Archive for the ‘Education’ Category

Learning environments relative to the utility industry

Naperville IL Smart Meter Deployment Campaign Hits a Home Run with Customers

Posted by Utilimetrics on September 8, 2011

The city of Naperville, Ill., earns high grades for the educational campaign it’s assembled to accompany the city’s smart meter deployment.

Customer engagement is one of the most critical aspects to consider when deploying a smart meter program. Without customer buy-in, deployments can go wrong quickly, or fail to get off the ground entirely.

The municipal utility of Naperville, Ill., hit a home run when it comes to customer engagement and education. Make that a grand slam. Naperville officials have deployed numerous programs to peak the interest of rate payers as the city prepares for a full rollout this November to its 57,000 customers, which includes 50,000 homeowners.

Naperville, a city of 145,000 residents located 30 minutes west of Chicago, has turned to innovative measures such as recruiting smart meter ambassadors to promote the Naperville Smart Grid Initiative, and measuring RF signals in an effort to alleviate concerns about health issues from the very low levels of RF emitted from smart meters.

According to Nadja P. Lalvani, community relations manager for the city of Naperville, outreach programs like these are groundbreaking when it comes to the electric utility industry.

Autovation attendees will learn first hand about the special customer engagement programs utilized by Naperville, as well as other details regarding its DOE grant and partnership. Dave Tilson, a senior manager with smart grid consultant West Monroe Partners, will join Lalvani at the podium. West Monroe assisted Naperville with its smart grid application, built the business case and also assists with community outreach.

Naperville has installed 80 meters out of a 200-meter pilot that will be completed by September. The city sought customer buy-in for the project immediately upon receiving its $11 million stimulus grant in 2009 and has created an interactive web site where customers can learn about the program.

The utility has relied heavily on three highly successful portions of their community outreach campaign.

  • Recruiting residential and business customers to act as smart meter ambassadors to spread the word about the initiative and its goals.
  • Deploying a Smart Grid Customer Bill of Rights.
  • Including thorough RF emission testing to assure the safety of smart meters

The ambassador program has been highly successful in utilizing an educated customer base to promote the program to fellow rate payers. So far, more than 30 customers have signed up.

“We’re very excited about this program and the benefits that will result,” says Lalvani. “As far as we can tell, no one else has implemented a program like this.”

Tilson notes that having customers promote the benefits of the program allows rate payers to form their own opinion of the smart meter initiative. “This is not just something coming from the city, it’s coming from customers and neighbors,” says Tilson. “There is a culture of not trusting the government, but that element is taken away by having this group of people advocate for us.”

The Smart Grid Customer Bill of Rights spells out the rights of customers in terms of the right to be informed, the right to privacy, and the right to data security.

When it comes to addressing safety concerns, Lalvani says that the city will measure RF emissions from smart meters and collector units, and then isolate those readings from whatever ambient RF emissions are present naturally in each neighborhood. The effort will cost about $25,000, mostly in hardware costs to purchase the measuring meter.

“This is being done in direct response to some concerns expressed by our residents on the safety of smart meters,” says Lalvani. “I have not heard of other utilities that have added this additional step to their projects. But we’ve been contacted by several municipal and investor-owned utilities that are interested to see the results of our testing.”

Naperville’s smart grid initiative benefits from the fact that its customers are very tech-savvy and interested in energy conservation efforts. For example, 25 percent of the utility’s customers have signed up for paperless billing, and 10 percent are enrolled in voluntary renewable energy programs. Additionally, 7 percent of cars registered in Naperville are hybrids.

“As we expected, our residents are very excited about this smart grid project, mainly because it is great for the environment and offers customers more options and tools when it comes to managing their electric usage,” says Lalvani.

Naperville’s city-owned utility was the only electric utility in Illinois to receive a stimulus grant from the American Recovery and Reinvestment Act, when the U.S. government distributed more than $3 billion to modernize the U.S. electric grid. The $11 million Naperville received represents 50 percent of the expenditure for the initiative.

The smart grid program is funded entirely by the municipality. When the program is fully deployed, the city will offer both flat rates and time-of-use rates, which will allow customers to save money on their energy bill by converting their energy usage to off-peak hours.

The presentation at Autovation is Tuesday, Sept. 27 at 3 p.m.

 

 

Posted in Autovation, customer engagement, Deployment, Education, Pre-Deployment, Project Management, Smart Grid, Smart Meters | 1 Comment »

Wireless Smart Grid on Stage at Autovation 2011

Posted by Utilimetrics on August 31, 2011

Communications technology is a hot topic at Autovation 2011 and Utilimetrics is pleased to have Josh Gerber of San Diego Gas & Electric and Joaquin Silva, president and CEO of On-Ramp Wireless (San Diego, Calif.) present their paper Communication Requirements for Improving Utility Efficiency in Smart Grid in the first education session Monday, Sept. 26 at 10:30 a.m. 

“Our strategy for the presentation is to discuss the segmentation of the applications for the smart grid,” states Silva. For example: From the substation to the meter on the customer premise, what are the data requirements and information requirements? And how do they vary across each of the applications, whether it is transformer automation? whether it is a meter, etc.? “We want to demystify some of this from a requirements perspective, specifically how it relates to the wireless requirements,” he adds.

After discussing the applications and how the wireless requirements vary, they will move on to some of the specific wireless approaches and technologies that can be used to solve the problems. “We plan to emphasize that it takes multiple types of wireless, depending on the application,” continues Silva.

“We will also talk about how to solve some of the very challenging problems of the smart grid,” he states. One example is that a very high percentage of the distribution grid assets are either pad-mounted or below ground, such as transformers and fault detection sensors. “For example, at San Diego Gas & Electric, 60% of distribution grid feeders are below ground,” states Silva.

This makes it challenging for wireless. You have to use multiple radio technologies to solve the problem. In one case, you may have an architecture where you have a low data rate and very high receiver sensitivity, needing a distributed wireless system or repeater-based solution. You need a higher data rate set of wireless solutions for more latency-sensitive applications.

“A good example is that a lot of utilities want to move toward dynamic volt/VAR control,” notes Silva. If you take the volt/VAR control problem from the substation down to the home, you have to collect the data from the volt/VAR information on various grid points, such as distribution feeder transformer and line sensors.

This is a challenging problem from a wireless perspective, because, again, 50% to 60% of the transformers are in pad-mount steel bunkers. “As a result, you have to be able to collect that data,” states Silva. “It’s not too latency-sensitive in terms of data collection.” However, you have to take into account the control loop for the other assets that exist on the distribution grid that are designed to dynamically manage it.

An example: If there is an electric vehicle plugged into a transformer, it impacts the whole VAR level sensor in the transformer connected to a wireless link that is able to penetrate into the pad-mount. It would sense that change and send an upstream alarm to a controller in the substation, or centrally-managed, which would say: “This has exceeded its threshold.” Now a secondary command in the energy management system would send a control message to a cap bank controller or switch that has the capability to dynamically change the volt/VAR configuration, or perhaps even shed load in the electric vehicle charging station if it is going to exceed a power level threshold on the transformer, which would cause it to explode.

“This is an example of where you need the pervasive wide-area sensing layer, and then a control system,” continues Silva. “However, there is a mismatch in the radio requirements for both. You can’t provide a control loop across the entire smart grid. It would bankrupt even the most well heeled utility.” As a result, according to Silva, you have to use a combination of two radio platforms – a more focused high-speed control layer that is managing the volt/VAR dynamic control layer, and a data collection sensing engine that gives you the pervasive wide area, including below-ground coverage.

Overall, what are the benefits of wireless? “Wired is extremely expensive in an already built-out distribution grid, because you have to lay cable or fibers,” replies Silva. “As a result, it’s not practical in many application segments. The substation typically does have fiber. However, between the substation and the consumer’s home, you need wireless.” Digging trenches and laying fiber typically does not work from a cost model, except in a greenfield situation. As a result, wireless is really the only way to have a low-cost sensing and control layer for the distribution feeder network.

There is still a place for wired, though, according to Silva. However, what the smart grid is all about is pushing out the connectivity and control that exists at the substation down the low-voltage feeder network. “As a result, in terms of growth, wireless applications and technologies are going to be far faster than cable,” he concludes.

 

Posted in Autovation, Education, Emerging Technology, Project Management, Smart Grid, Smart Meters | 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 »

Learning Lab at PGE Offers Something for Everyone involved in AMI

Posted by Utilimetrics on July 11, 2011

AMI experts at Portland General Electric, one of the most forward-thinking utilities in the U.S., are preparing an insightful and dynamic Learning Lab for Utilimetrics Thursday, July 28. Tentatively, the Learning Lab is divided into six segments. News Link spoke with the PGE staff members who are developing the learning lab.

The first segment will focus on smart metering at PGE. “We plan to explain the entire smart metering project,” states Dean Smith, project communications manager. “We completed the deployment and are in the operational phases. We will cover the business case, vendor selection process, meter deployment, tower and network deployment, and lessons learned getting it through to the operational phase.”

This segment will include business process improvements PGE made, including various changes that involved process automation. “These were coupled with the smart metering installation, so we could immediately leverage the benefits from the system through a series of business process improvements,” continues Smith. “We will share the benefits and value these improvements have provided, as well as some of the lessons learned.”

Eric Spack, AMI project director is the featured speaker in the first segment. Spack will discuss the AMI project, including major milestones and a major lesson learned, “plan to re-plan.” Spack will talk about the importance of communicating with customers and how to avoid generating ill will that could expand into an “opt out” initiative or consumer push-back situation. He will discuss the “care and feeding” of the call center before and after deployment.

“Another important element is focusing and prioritizing the business process and IT software development initiatives,” explains Spack. His message: “You will underestimate this effort, and you will get a late start.” He will then discuss how to recover and make sure the most critical items get done first, in order to ensure project success and maximize the return on investment.

The second segment’s focus is the mass deployment and customer relations elements of smart metering. “We will drill down to meter deployment – what the deployment practices were, how they went, what we learned, and what the customer relations component of the whole deployment process looked like,” states Smith.

Jamie Swails, manager, Network Data Operations Segment will speak in the third segment. “We will provide information on our organization and what we do,” states Swails. “We will then explain some of the lessons learned and areas of concern. For example, what is our volume of exceptions? How many people do we have dealing with exceptions? What are some of the unexpected operational impacts related to hosting the system?” Swails plans to talk about billing, since the exceptions can carry through to billing. “There were some heavy impacts to our billing department that were not anticipated as part of the project,” she explains. “Currently, we are reading 800,000+ meters over the air. We are able to provide 99 percent of the readings on-time to our billing department.” Swails will share other anticipated challenges. One relates to maintaining all of the data, such as data privacy concerns, scalability concerns, and how this amount of data will affect department heads. “I will also discuss what it means to be a steward of that meter data,” she states.

The fourth segment covers a number of subtopics, including meter data management (MDM). “We will talk about our MDM system, how the end-to-end processing of data through our MDM system into our enterprise system takes place, and what we have learned about integrating these systems together to create an effective end-to-end system,” states Smith.

The fifth segment focuses on energy recovery and related field operations. “We will talk about what we are learning about how to use the system in the field,” says Smith. Areas where PGE is receiving benefits include energy recovery, theft detection, and line losses. “We are also looking at new ways to leverage the system, such as transformer-level metering and fault detection,” he continues. “Not only do we have a business case that anticipated certain benefits tied in with business process automation, but we are finding there are other things we can do with the system that, as people become more familiar with the data and how to use it, can be of additional value on the operational side.”

Segment six is about future-related smart grid initiatives. “Here, we will share some of our smart grid thinking, such as how smart metering ties into a smart grid application, including distribution automation,” states Smith. “We are doing some pilot projects in this area.”

One of the featured speakers in this segment is Conrad Eustis, director of Retail Technology Development who will discuss the appliance’ interface. By the end of July, it should be ready to go to a standards organization. Eustis will also discuss EPRI’s “Plugfest,” which demonstrates the interoperability of the standard. And, he will talk about the future of the smart grid in general.

The Learning Lab is more than just PGE people standing up and talking, though. “We are also going to do some ‘show and tell’ on our distribution generation control center, our MDM, and other elements,” notes Smith.

Prior to the Learning Lab, PGE will ask participants about specific topics they would like covered. “We want this to be as relevant to participants as possible,” emphasizes Smith. “We will present information, and leave time for people to interact and drill down.”

And for participants who want to continue learning, on Friday, July 29 PGE operations personnel and other experts are available to meet individually with participants and discuss areas of specific interest.

The fee for participation is $295 for Utilimetrics members and $395 for nonmembers. For information or to register, click here.

Thanks to the Learning Lab sponsors: Sensus and Wellington Energy.

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

Innovation is the Name of the Game at Autovation Host Utility DC Water

Posted by Utilimetrics on May 20, 2011

The District of Columbia Water and Sewer Authority, now known simply as DC Water, has a fairly broad agenda designed to help the organization evolve. It is being spearheaded by George S. Hawkins, general manager, who was named to his position in September 2009. Before that, Hawkins was director of the District Department of the Environment, an agency that performs city, county and state environmental functions for the nation’s capital.

The agenda is being driven by some significant issues that Hawkins sees as facing DC Water and the water utility industry in general. “Those of us in the industry understand well the vital nature of what we deliver for every living organization,” he states. “We also understand just how poor the condition of the infrastructure is in most places, including here.” However, he points out, very few consumers really understand what the utilities do. “Few people know where the water comes from when they turn on the faucet or where it goes once it goes down the drain,” he states. “As a result, the financial model that we utilize is broken. If people don’t understand what we do, it is very difficult to raise the kind of revenue we need to invest and improve the system.”

In response, DC Water has created a comprehensive program designed to respond to these challenges. There are two elements to the program. One involves providing more and better external communication with customers. The other involves providing better service to customers through internal improvements.

Communications

The first step was the organization’s rebrand. “We wanted a name, logo, and tagline that would make us much more visible and easily accessible,” he explains. The new name is “DC Water.” The logo is a green “DC” with a large blue water drop. The tagline is “Water is Life.”

Next is a very aggressive use of every communication media that DC Water staff can utilize. A key element of this involves constantly updating the utility’s website. Each month, DC Water provides a report card on its performance indicators, such as how often it achieves first-call resolution when customers call, how quickly it answers calls, how many water main breaks it experiences, how quickly it repairs these water main breaks, how many of its fire hydrants are out of service, how well it meets its environmental obligations, and so on. “We also have a Facebook page, and we are on YouTube and Twitter,” continues Hawkins.

In Spring 2011, when DC Water proposed its rates for the 2012 budget, the law required that it hold a public hearing. DC Water went above and beyond that requirement. “We held dozens of meetings, with virtually every audience we could think of,” reports Hawkins. “We didn’t want to shy away from anyone. We wanted to go out and tell our story – what we are doing and why it matters to people. Our belief is that, the more the public understands what we do, the more we hope they will understand and support the kind of revenue we need.”

Service

The other side of the program focuses on what DC Water can do to improve the internal workings of the organization, so it can improve the service it provides to customers and do so more cost-effectively.

There are three prongs to this:

  1. The Team Blue Project is what Hawkins defines as “classic organization development.” “We selected a series of issues that everyone cares about,” he explains. The most important two are safety and asset management. There is a cross-functional and cross-organizational team in place for each of the issues. Members include employees from every level of the organization and across the various disciplines of the organization. The teams are empowered to come up with recommendations on what DC Water should do. It is then senior management’s responsibility to implement as many of these recommendations as possible. There are two purposes for Team Blue. One, of course, is to improve the organization. The other is to provide employees with the opportunity to participate more in the organization.
  2. “We will launch the second prong this summer,” continues Hawkins. It is tentatively called the DC Water Science and Innovation Program (SIP), a formal mechanism designed to allow and encourage all employees throughout the organization to come up with ideas on how DC Water can do anything better – answering phones, filling out permits, turning valves, digging in the streets, managing nutrients at the wastewater treatment plant, and so on. These ideas can be on any scale – large to small. “An idea might be a way to do our jobs better for the same money, or actually save money doing the same job,” he notes. DC Water wants to collect these ideas, then highlight them on a website where people can vote for the ideas they think are good. The ideas will then be reviewed by a panel of experts, and if an idea is selected and implemented, DC Water will provide visible recognition to the employee who came up with the idea. “We haven’t figured out yet if we can legally do this, but perhaps we can provide employees with financial bonuses,” says Hawkins.
  3. The third prong is a very aggressive program, primarily, but not exclusively, with IBM. DC Water is working with IBM on “Smart Water,” which is an outgrowth of IBM’s “TheSmarterCity” program. “We will be designing analytical products that can take the kind of information that we already collect and use it to make smarter decisions, such as anticipating problems and predicting maintenance,” reports Hawkins. One example might be information that will allow the utility to know which pipe might break next. This will allow crews to select and plan work more intelligently. “IBM is working with us and developing some new software products for this,” he adds.

Results

Although these initiatives are all relatively new, DC Water is already seeing some impressive results.

On the communications side: “There is no question that the public is already more aware of who we are and what we are doing,” he states. “While we still get complaints, we are getting a lot more support. We also have much better relationships with local political leaders.”

On the service side: DC Water is receiving a lot of good ideas from employees that are coming in informally, in advance of the formal launching of the SIP. “Someone came up with an idea of how to use credit cards differently for some past debts,” states Hawkins. “This has helped us save several hundred thousand dollars.” An engineer came up with a better idea for fixing water line breaks that is saving the utility several million dollars. “We are also saving enormous amounts of money in personnel and gasoline costs by implementing a first-of-its-kind automatic meter reading program for our water valves, which are now read electronically,” he explains.

Autovation

DC Water is a host utility for Autovation 2011 Sept. 25-28 in Washington, DC. Hawkins will discuss these innovations during the Autovation Opening General Session Monday, Sept. 26. Hawkins also plans to talk about how he thinks the water utility industry needs to innovate and be flexible in terms of the products that it sells, not just how it does the work. Examples: There are millions of people who visit Washington each year. Most of these people, when they drink water, are drinking bottled water. “In essence, we have ceded that market to private bottled water companies,” he admits. The question: “What kind of device and apparatus can we come up with in order to get people to use public water, and in a way that we can capture some revenue?” he queries.

DC Water occasionally invents things to make its wastewater treatment plants work better. The question: “Can we monetize these products by joint-venturing with a private firm, so that not only are we providing innovation to our operations, but also increasing our sources of revenue?” he asks.

Hear Hawkins discuss many of the great innovations happening at DC Water, then see some of them in action at the Bryant Street Facility tour Wednesday, Sept. 28. Check out the Autovation website for information.

Utilimetrics is the world’s premier utility technology association, providing advocacy for utilities and information about innovative technologies that lead to improved operations, customer service and resource utilization. The association brings industry professionals together to share lessons learned, best practices and future needs. Utilimetrics focus is on the deployment of intelligent technology and enhanced utility operations to best serve customers. For more information go to: www.utilimetrics.org

Posted in Autovation, Clean Technology, Deployment, Education, Emerging Technology, Project Management, Smart Meters | Leave a Comment »

Profile: SCE’s AMI/MDM Smart Grid Strategy

Posted by Utilimetrics on April 29, 2011

Southern California Edison is regulated by the California Public Utilities Commission, which mandated SCE and the other two IOUs in the state to implement smart metering programs.

SCE responded by creating an advanced meter infrastructure project called Edison SmartConnect, which will replace approximately 5 million electric meters for residential and commercial customers below 200 kilowatts in demand with “next generation” smart meters by the end of 2012.

“The goal is an infrastructure that will enable utility companies to partner with their customers to lower peak demands,” explains David Erickson, director of IT and Business Integration, Edison SmartConnect. “We can do this by providing information and data to customers that they have never had before.”

For example, residential and commercial customers will be able to see their usage in 15-minute and hourly increments, respectively, and can see usage patterns. The system will also be able to provide customers with time-of-use peak and off-peak rates.

“Customers can sign up for us to turn off their air conditioning during certain events and receive incentives,” he adds.

The System

Each morning at 8 a.m., customers who are “hooked up” can see their usage for the time period of the previous midnight and back. This provides them with 720 reads per month (24 daily reads x 30 days), rather than the traditional one they receive with their monthly bills.

Getting the system up   and running has been and continues to pose challenges. SCE has a 50,000 square-mile service territory, with 14 million customers and 5 million actual accounts. “We will have smart meters in all five million accounts,” reports Erickson.

As can be imagined, a lot of logistics has been involved in developing the Edison SmartConnect program, from the initial planning of how SCE was going to deploy the meters to how it would stage warehousing activities, as well as how it would strategically work through its service territory, district by district.

“We are replacing about approximately 6,500 meters a day,” states Erickson. “However, there have been days where we replaced 10,000 and even 12,000 meters.” Between September 2009 and April 2011, SCE has deployed about 2.5 million meters. It will have the remaining meters deployed by the end of 2012.

The Technology

Besides the logistical considerations, there is also the technical systems infrastructure to consider. This involves collecting, processing, validating, loading, and storing of data, so customers can access the information to use for energy management purposes, and so SCE can access it for billing purposes. The technology includes a Network Management System (NMS), a Meter Data Management (MDM) system, and the smart meters themselves.

The NMS collects the data from the meters, communicating with them using a local area mesh network that feeds up into a cellular network. “We send a command to the meter to request usage data,” he states. “The meter sends the data back through the network.” It then goes to a cell tower, and from there comes back to SCE’s data computer center, where the NMS receives the data from all the meters.

SCE sends the commands out about 1 a.m. each morning to all meters. However, the information comes back at different times. About 50% are back by 2 a.m., and 99.9% are back by 6 a.m. 

The NMS then passes the information on to the MDM, which takes the interval data and makes sure the information is valid. “If we don’t get data back from certain meters, we estimate the gaps in the interval data,” he explains. For each account, SCE will correlate the data and run it against the rate that it has for each customer. This will provide the determinant to create the bill. This data is then passed back to SCE’s legacy mainframe billing system that it has had for many years. The billing system then creates the bill.

Once the data is validated by the MDM, it is also sent to the data warehouse. “We have a separate system and we store it in the data warehouse,” states Erickson. As a result, when customers log onto the SCE website at 8 a.m. they can directly access SCE’s data warehouse to view their usage. 

The MDM also allows SCE to remotely turn service on and turn off, instead of having to send a field service rep out to do so. “This takes about eight seconds,” he reports. 

Interval Billing

A key element of Edison SmartConnect is interval billing. “Interval billing is driven by the MDM,” explains Erickson. “The complexity of this begins with the business requirements that we had to satisfy with our system to provide the capabilities we wanted.” SCE had about 2,500 specific internal business requirements, which translated into over 5,000 system requirements. This translated into about 2,000 test scripts and about 7,000 test conditions. “We also did ‘performance of scale’ testing,” he continues. “These systems are built for certain throughputs and thresholds by the vendors. However, we wanted to make sure they would perform with the numbers we needed – five million meters. We didn’t want to make an investment like this and find out down the road that there would be problems that would prevent us from doing more metering or billing.”

SCE began testing the interval billing in January 2010 and began implementation in October 2010. Currently, SCE has about 150,000 accounts that are part of the interval billing program. “By late summer, we expect about one million customers to be getting their bills with interval billing,” he states. “I will talk a lot more about this testing during the Utilimetrics webcast May 4.”

Benefits

Obviously, the most important benefit of Edison SmartConnect will be the ability to reduce peak demand requirements. “It will also help us with the interface between smart meters and the outage management system, which we will be starting in June 2011,” states Erickson.

Furthermore, it will help SCE prepare for the future implementation of “home area network” technology, which will allow customers to have in-home digital displays for energy management and will tie into the smart meters and programmable thermostats.

Join Erickson Wednesday, May 4 at 12:30 p.m. Central for a webcast on Edison SmartConnect’s Meter Data Management System. Click here to register or for more information. The webcast is free for Utilimetrics members.

Posted in Autovation, Deployment, Education, Meter Data Management, Pre-Deployment, Project Management, Public Policy, Smart Grid, Smart Meters | 1 Comment »

Dismantling the Myths about Smart Meters for Electric Customers

Posted by Utilimetrics on April 4, 2011

As any utility in the deployment or post-deployment stage can attest, there is much more to a successful installation than purchasing the right technology and ensuring it is successfully installed. Customer acceptance is vital; without it, utilities may face uphill public battles. And for some utilities, those battles are very painful.

Customer reluctance ranges from letters to the editor to protests to refusing to allow the meter change outs. Some communities have formed groups to fight the installation of smart meters.

Why all the hostility against a technology that has been proven to help consumers monitor energy and conserve valuable resources? Myths! There are a number of myths surrounding smart meters, and although none have been validated, many consumers believe them.

The three most common “myths” are:

  1. Smart meters cause health problems because of the radio waves or electromagnetic waves
  2. Smart meters will compromise a family’s security and privacy
  3. Smart meters will cause rates to increase

Health Issues

“The claimed health effects of radio frequency is a burning topic these days,” notes Ralph Abbott, founder of Plexus Research – SAIC. “There are groups of people who believe that we live in a ‘soup’ of RF energy, or EMFs, that can cause cancer. Sources of concern include televisions, microwave ovens, and cell phones.”

To date, there is no documentation that this is true. According to Ralph, most of the research has been commissioned by the cell phone industry. As a result, some people claim this is industry-biased.

Things are different with smart meters. The reason is that individuals can make the decision whether or not to use a cell phone. “They can’t decide to reject having a smart meter installed,” notes Ralph. “The citizens of Marin County, California, have outlawed smart metering, and there are county statutes against any further deployment.” In addition, some citizens have petitioned the California PUC to halt all further deployment of smart meters in the state. However, there is a legal battle going on over this, according to Ralph, because the Federal Communications Commission (FCC) reserves the right to make determinations about health matters.

Utilities need to find a way to separate rumor, speculation, and junk science from real science that is conducted by qualified people, according to Ralph. “Most of the work done on this, though, is by utility agencies, he states.  ”Authoritative reports are available to consumers showing that the levels of radiation are absolutely miniscule, especially compared to cell phones.” However, he adds, consumers can simply say they are biased, because they are written by the utility industry.

Recently, the California Council on Science and Technology came out with a report showing there is no problem. “Fortunately, the CCST report has an impressive list of academics and scientists who are not part of the utility industry, making it as objective as possible,” notes Ralph. “As a result, this report is starting to have some positive impact around the country.”

Security/Privacy Issues

According to Andrew Brock, president of Rio Tronics, considering the increases in credit card fraud, identify theft, and Internet information being compromised, it is understandable consumers may have concerns about privacy and security issues related to smart meters. “In response, some regulators are saying that, while aggregate data can be made available publicly, data on individual consumers should only be made available to those consumers,” he states. “Utilities should also emphasize to customers just how secure the data is because it is well encrypted.”

“One thing smart metering does is determine usage every hour or 15 minutes,” notes Ralph. “This can provide information on whether someone is home, so if a nefarious individual was able to access this data, they could try to figure out if you were home.” However, according to Ralph, this information isn’t particularly useful, because usage levels will change if heating or air conditioning go on or off, and this can occur whether the person is home or not. In addition, he adds, NIST (National Institute of Standards and Technology) is creating cybersecurity standards that will require data to be encrypted and afforded a number of other forms of protection.

Billing Issues

According to Andrew, there have been a couple of studies done on the question of smart meter accuracy by a California utility to help allay its customer concerns. “The studies confirmed smart meters accurately record usage, the systems are correctly processing data, and there are no systemic issues, other than a few exceptions,” he reports.

However, he adds, some additional details were missing. “For example, the utility should have explained to customers that the electro-mechanical meters being replaced by smart meters could have been running slower over time,” notes Andrew. “As a result, bills might have increased because of the improved accuracy of the smart meter.” The utility should have also explained that the deployment of the smart meters coincided with a heat wave, and this caused some customers to assume that the smart meters were at fault for their increased bills. “Third, there were also some incorrectly applied rates that are now being corrected,” he adds.

When educating customers about smart meter accuracy issues, Andrew believes the industry should emphasize the data they will be getting will eventually allow them to reduce their bills by better managing their usage.

General Strategies

While there are some specific approaches the industry can take when dealing with the myths, Andrew believes strategies can and should be similar for all three concerns. He recommends five steps:

  1. Listen to your customers’ concerns and needs. Ignoring them will only make things worse.
  2. Educate your customers with information related to their concerns.
  3. Prepare the proper type of pilot program, one that involves customer segmentation, customer education, the opportunity for customer feedback, response to that feedback, and making customers partners rather than adversaries.
  4. Roll out the program slowly, learning along the way.
  5. Finally, offer an opt-out provision. “You will always have those who won’t trust anything you say related to health issues, privacy/security issues, and cost issues, so you can just let them choose not to participate,” states Andrew.

Ralph believes that, by using the right combination of education and other strategies, the industry should be able to calm the concerns of most rational citizens. “However, you may never be able to reach those who are on the fringe,” he admits.

 

Posted in Clean Technology, Demand Response, Department of Energy, Deployment, Education, Emerging Technology, Home Area Networks, Pre-Deployment, Project Management, Public Policy, Smart Grid, Smart Meters | Leave a Comment »

 
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