Archive for the ‘Pre-Deployment’ Category

A process involving building a business case, justifying cost, vendor selection and implementation of planning

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 »

Change Management Enables Smart Grid Innovation

Posted by Utilimetrics on August 25, 2011

The way we produce, distribute, and consume electricity is changing and a paradigm shift has begun. Nowhere is this statement truer than in the Province of Ontario, Canada.  These changes are part of a global trend that Ontario is leading—and propelled by. The province is among several jurisdictions around the world that have recognized the need to modernize their electricity systems to fully capture the economic and environmental benefits of this transition.  These are exciting times.  Ontario’s electricity system is truly in transition.  The pace of change is unprecedented in many ways.

Ontario-based Hydro One is involved in a number of initiatives designed to sustain and modernize Ontario’s electricity grid. These initiatives are bringing substantial changes to the way Hydro One operates the system, including new business processes, skill sets, and opportunities for staff. However, the concept of a “smart grid” is generally not well understood by consumers and utility employees have only recently been introduced to the strategic importance of smart grid development.  Hydro One’s Advanced Distribution System (otherwise known as Smart Grid) Project Team is implementing change management strategies and tactics to build awareness and engage employees so they can contribute to building the solution they will benefit from.           

Kathy Cowan Sahadath is program manager for Hydro One Networks and is a change management professional within the Hydro One Corporate Projects group. “I have the good fortune to be involved in a lot of our major business transformations,” she states. Over the last 10 years or so, she has been involved in an Operating Grid Control Centre amalgamation, major SAP implementations, Smart Meter implementation, and now Smart Grid (which Hydro One calls “Advanced Distribution System”). Cowan Sahadath helped create the change programs for the projects, as well as bring together the teams needed for the projects. 

For the Advanced Distribution System project, Cowan Sahadath recruited Deb Bradbury, a principal consultant with Enspiria Solutions a Black & Veatch Company to be a vendor partner. “We now have a full change team that is working through the different phases that we have designed for this project,” states Cowan Sahadath.

Hydro One started to think about its Smart Grid strategy back in 2008. It began by asking what a roadmap for smart grid would look like for the next five to 10 years. What evolved from this was a Steering Committee that led to the birth of a project team. 

“It has been exciting to see the process evolve over the last three years, as well as to see the enormous scope of what our industry is facing,” continues Cowan Sahadath. “Our Autovation presentation will provide more information on the details of the scope of our project.” Cowan Sahadath and Bradbury will speak Wednesday, Sept. 28 at 10 a.m. on the topic “Change Management Enables Smart Grid Innovation.”

From a change management or business transformation perspective, Cowan Sahadath believes that there is tremendous opportunity to rethink how Hydro One does business. “What the utility industry is facing is an opportunity for major changes in how we do business and how we interact with our customers in the future,” she adds. As a result, she believes, while the technology is very important, there is a huge human element the utility has incorporated into all of its plans and implementations going forward. “This is why I think change management and transformation is so important,” she states. “It is an opportunity for us to start to help influence a change in that mindset with the employees, as well as with our customers and stakeholders outside the company.”

“We will also present information on the unique challenges we are facing with this project,” states Bradbury. “It is very complex. We have a large project team with 10 different work streams, so there are challenges with coordinating and communicating the important decisions that impact the work in progress.” She adds: “We know the tools and data the new technology provides as well as new business processes will offer employees opportunities to make better business decisions and to work more efficiently and ultimately improve operations.”

Another challenge, according to Bradbury, is: How do you get employees to buy into all of this and be willing to change how they work? They want to know how much it will really help them.

As a result, one large part of the initiative involves business process reengineering – taking a fresh look at existing processes to determine how new tools and information will improve the quality and timeliness of business decisions. For example: How will Distribution Engineers do real-time studies? How will the Control Room and Provincial Lines deal with planned and un-planned outages? How will the Control Room deal with new alarms?  How will Distribution Controllers and Dispatchers be able to target where to send crews more accurately? “We are taking a fresh look at all of these things and determining what the future will look like,” adds Bradbury.        

So what is Hydro One doing to facilitate change management? A lot of things. “From a change management perspective, we have involved the key stakeholders right up front,” replies Bradbury. “Even in Phase 0, when we were just planning, we had representatives from lines of business at the table who we expected would be impacted.  Ultimately, they are the ones who have to do the work, so they have to be part of the decisions, and they have to believe in it.”          

Another key has been being sure the utility has very active and visible leadership throughout the process. This includes participating on the Ontario Smart Grid Forum and staying aligned with the Ministry of Energy.           

Communication is also important, according to Cowan Sahadath. “At every step of the process, we need to make sure that there is frequent and open communication,” she states. “It also needs to be two-way, so that there is good opportunity to listen to people and get feedback.”

Bradbury agrees with the importance of communication. “We have developed a very detailed communication strategy and plan for our different stakeholder groups,” she states. “We are currently executing an Awareness Campaign and using many communication vehicles which we will describe during our Autovation presentation.”

According to Cowan Sahadath, because smart grid development is still so new and untested, there are not a lot of “best practices” from which Hydro One can learn. “As a result, along the way, we, as an industry, need to leverage the knowledge and information from our own work as well as other utilities as quickly as possible,” she emphasizes. “In fact, the ideal is to share ‘lessons learned’ in almost a real-time environment.”           

And this, in actuality, is what Utilimetrics and Autovation are all about.

Posted in Autovation, Change Management, Deployment, Pre-Deployment, 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 »

Intelligent Water Management Systems Usher in a New Age for Water

Posted by Utilimetrics on July 12, 2011

Intelligent Water Management Systems Usher in a New Age for Water

By Doug McCall, director of marketing, Sensus

Water utilities are choosing intelligent water management solutions to maximize the efficiency of the entire water distribution system as global demand for water steadily increases and supplies are strained. Based on the current rate of consumption, a global water shortage of 40 percent is estimated by 2030.

For water utilities trying to strike a balance between consuming and conserving water, the impetus to find more intelligent solutions for water management is great. Many water utilities operate at a financial loss each year, as unaccounted for water usage due to inaccurate meters and aging infrastructure translates to an untold amount of lost revenue.  

One in three utilities is in deployment

A 2010 Oracle study found that one in three water utilities were not only in some phase of implementing a smart water program, but that these respondents viewed early leak detection, supplying customers with tools to monitor and reduce water use and reducing overall water demand as  the most important benefits of these systems.

Water conservation benefits of an intelligent water management system were almost immediately evident in the City of Santa Maria, Calif. Santa Maria began implementation of an intelligent water management system in 2010 with a 45-day pilot program that quickly identified leaks in approximately three percent of test homes. In the first eight months after broader system deployment, city officials estimate they saved more than eight acre feet, or more than two million gallons of water, reducing the amount of water Santa Maria needed to purchase from the state. Santa Maria customers also realized the cost benefits and savings provided by leak detection.

In addition to Santa Maria, water utilities across the country including the Albuquerque-Bernalillo County Water Utility Authority, Garden City, Kan. and the Town of Cary, N.C. are implementing intelligent water management technologies that help maximize resources, conserve water and boost operational efficiency and customer engagement.

Increased operational efficiency

Intelligent water management systems offer utilities benefits such as increased operational efficiency and strengthened customer engagement. Leak detection and building consumer awareness of water usage are two benefits of deploying intelligent water management solutions that will sustain and improve quality of life for communities around the world.

Another California city, Redwood City, sought a more aggressive water conservation solution in 2008. A three-year drought stressed the volume of water Redwood bought annually from the San Francisco Public Utilities Commission for its 83,000 water customers.

In lieu of heavy rationing or overuse penalties, Redwood City officials developed the “Budget-Based Rate Program” to empower landscape customers to make proactive changes in their consumption by creating tiered pricing based on daily conditions and each landscape customer’s anticipated activities for the day. Redwood City deployed a real-time metering solution built upon the Sensus FlexNet communications network to provide customers information on their water usage and rate pricing data to support informed decisions about water usage.

Customer engagement pays off

Redwood City’s program encouraged customers to conserve water and stay in line with water budgets to pay the least of three rate tiers for water. Redwood City created a web portal to calculate each irrigation customer’s water budget based on weather patterns and anticipated activities for the day, considering factors including the size of a property and whether there was a swimming pool or landscape design requiring additional water. The system also enabled Redwood City to establish an email module alerting customers of potential overuse or continuous leaks.

With these tools, Redwood City was able to save more than 80 million gallons of water in a year and some customers were able to save as much as $50,000, becoming a prime example of how intelligent water management can facilitate water conservation and empower water utility customers to make smart choices about water consumption.

Water consumption evaluation needed

Due to major global changes, less than 10 percent of the world’s freshwater supply is available for domestic use, necessitating a reevaluation of how the world delivers and consumes water. Intelligent water management will help modernize water utilities and prepare for a world where cost, legislation, and supply dictate changes in our relationship with water.

Posted in Autovation, Deployment, Emerging Technology, Pre-Deployment, Project Management, Smart Meters, Water utilities | 3 Comments »

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 »

Utilimetrics Smart Utility Marketplace Offers Unique Search Engine

Posted by Utilimetrics on June 21, 2011

When utility technology leaders are ready to buy, they turn to Utilimetrics’ Smart Utility Marketplace to cut through the clutter of traditional search engine results. Imagine blending an internet search engine with the structure of the Yellow Pages. It’s all there with the Smart Utility Marketplace

Within the Marketplace, users easily locate products and services unique to our industry without the clutter of a general Internet search engine. Additionally, the Marketplace offers another fantastic feature – a Product Showcase that allows users to view specific products and special offers right on the front page of the guide.

Users have the option of performing keyword-driven searches, or a category-specific search. Both methods produce the most industry-relevant results on the Web, and the Marketplace is updated and corrected continuously, unlike a printed directory that is often outdated by the time it is printed. Experience how much more convenient it is to toggle from the online guide to spreadsheets and other web data than refer back to print directories.

The Smart Utility Marketplace allows you to search for specialized providers of desired goods or individual products. In addition, the downloadable Desktop Search application enables you to search for items directly from a small search window on your computer desktops, making the search process as convenient and time-efficient as possible. You’ll have instant, one-click access to the buyers guide and the Utilimetrics website at any time.

For suppliers, there are many advantages to advertising in the Smart Utility Marketplace, including cost and flexibility. For a small administrative fee a supplier company can prominently display its company logo, offer complete contact information, and provide a detailed company description and profile page. And, online content can be updated within seconds at any time, with no added cost. If you’d like more information on advertising options, contact Utilimetrics’ partner, MultiView, Inc., at 800-816-6710 or Utilimetrics@multiview.com.

From a user’s perspective, the procurement of resources for your business or facility can be the key to success within the industry. Whether you’re looking for supplies and services, or simply the essential tools and accessories you need to satisfy your customers, the Smart Utility Marketplace can help. It’s a powerful online tool that will help change the way you search for industry related resources. Why not try it for yourself? Start your search at the Utilimetrics homepage (www.utilimetrics.org), and click on the Smart Utility Marketplace.

Posted in Autovation, Clean Technology, Cybersecurity Issues, Demand Response, Deployment, Emerging Technology, Home Area Networks, Meter Data Management, Pre-Deployment, Project Management, Smart Grid, Smart Meters, Transmission and Distribution Technologies, Water utilities | 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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