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Power to the People: Automatic Meter Reading Supports Consumer Programs

September 2015

"Customers look at their utility bill a total of 9 minutes a year," says Doug Horton, manager of Revenue Requirements at NSTAR, a Northeast Utilities company. Typically, "it's just not something the average customer monitors daily." So, it can be hard to motivate customers to use less electricity, even if it means lowering their energy costs. With its project in the Smart Grid Demonstration Program, NSTAR sought ways to incentivize consumers to participate in dynamic pricing and direct load control (DLC) programs. As part of the $4.9-million project, which began in 2010 with $2.4 million from DOE through the American Recovery and Reinvestment Act, NSTAR used e-mails, postcards, direct mailings, and bill inserts to recruit customers living in and near Boston.

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Iowa Association of Municipal Utilities Smart Grid Thermostat Project Final Project Description

August 2015

The Iowa Association of Municipal Utilities (IAMU) Smart Grid Demand Response Project comprised eight municipal utilities implementing advanced "smart" technologies. The project deployed advanced metering infrastructure (AMI) systems, a customer web portal, direct load control switches, programmable communicating thermostats, and a dedicated paging system to support demand response.

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South Mississippi Electric Power Association - Advanced Metering Infrastructure and Associated Smart Grid Investments for Rural Mississippi - FINAL REPORT

August 2015

South Mississippi Electric Power Association (SMEPA), a generation and transmission cooperative, deployed an advanced metering infrastructure (AMI) system to benefit not only SMEPA but also five of its member distribution cooperatives: Coast Electric Power Association (Coast), Magnolia Electric Power Association (Magnolia), Pearl River Valley Electric Power Association (Pearl River), Southern Pine Electric Power Association (Southern Pine), and Southwest Mississippi Electric Power Association (Southwest). The AMI system has enabled two-way communication between SMEPA and its member cooperatives' substation meters and between the member cooperatives and their customers' meters. Additionally, three of the member cooperatives (Magnolia, Southwest, and Pearl River) implemented supervisory control and data acquisition systems.

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East Penn Manufacturing Co. Grid-Scale Energy Storage Demonstration Using UltraBattery Technology Final Technical Performance Report

August 2015

The collaboration described in this document is being done as part of a cooperative research agreement under the Department of Energy's Smart Grid Demonstration Program. This document represents the Final Technical Performance Report, from July 2012 through April 2015, for the East Penn Manufacturing Smart Grid Program demonstration project.This Smart Grid Demonstration project demonstrates Distributed Energy Storage for Grid Support, in particular the economic and technical viability of a grid‐scale, advanced energy storage system using UltraBattery technology for frequency regulation, ancillary services, and demand management services.

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Knowville Utilities Board Impact Metrics Report: Experience using the MultiSpeak Protocol

August 2015

In April 2010 KUB was awarded a Smart Grid grant from the Department of Energy (DOE) and thus began the Knoxville Community Smart Grid Project. This document is focused on KUB's experience in using the MultiSpeak protocol to integrate Advanced Metering Infrastructure (AMI) information to KUB's enterprise systems using service oriented architecture (SOA), or web services. KUB established SOA in 2006 and purchased IBM Web Sphere to function as an Enterprise Service Bus (ESB) in support of KUB's customer web site. Since then, the majority of KUB's enterprise application integrations have leveraged web services across the ESB. These systems include, but are not limited to: Customer Information System (CIS), Outage Management System (OMS), Human Resources Information System (HRIS), Geographic Information System (GIS), Financial Management System (FMS), and Interactive Voice Response (IVR). More recently, smaller systems, such as custom developed and nonenterprise applications have begun integrating via the ESB. As a result, KUB currently has permanent staff experienced in web service development. The following are a few examples where web services provide an advantage over non-SOA methods: more powerful routing and automation across multiple systems; easier integration when upgrading or replacing systems; better error logging and handling; and greater programmatic flexibility. Regarding the MultiSpeak protocol, the National Institute of Standards and Technology (NIST) has developed a Smart Grid Conceptual Reference Model as part of its Smart Grid Standards Framework and Roadmap. NIST has chosen MultiSpeak as a key standard in the Operations area. According to the web site http://www.multispeak.org, " the MultiSpeak specification is a key industry-wide standard for realizing the potential of enterprise application interoperability." The site also states, "The MultiSpeak specification helps vendors and utilities develop interfaces so that software products from different suppliers can interoperate without requiring the development of extensive custom interfaces," and "the MultiSpeak specification defines what data need to be exchanged between software applications in order to support the business processes commonly applied at utilities." As a result of the success of the multiple ESB integrations, KUB has adopted web service/ESB integration as the preferred method of integration. Therefore, KUB applied this technology when developing the Smart Grid project related integrations, and MultiSpeak offered a SOA-oriented solution.

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NV Energy Nevada Dynamic Pricing Trial Interim Report Vol 1-4

August 2015

This interim report covers analysis and results of Nevada Dynamic Pricing Trial (NVPT) operations from its formal inception with recruiting in January 2013 through the close of the first program year February 28, 2014. The NDPT Final Report to be submitted in September 2015 will cover analysis and results of operations from the program's inception through the close of the second program year February 28, 2015. Clicking on the title above, of the cover graphic will download a zip file of the four PDFs. Alternatively, you can download any one of the volumes below. The volumes are: Volume 1: Design & OperationsVolume 2: Program Year 1 Data AnalysisVolume 3: Program Year 1 Direct Customer ResearchVolume 4: Appendices

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Consolidated Edison Company of New York, Inc. Smart Grid Investment Grant Project - FINAL REPORT

August 2015

The Consolidated Edison Company of New York, Inc. (Con Edison) Smart Grid Investment Grant project involved installation of smart grid systems and components to enhance the electric grid's performance and operating flexibility. The project installed distribution automation systems and equipment on 840 out of 2,297 circuits. Con Edison also deployed upgrades to the supervisory control and data acquisition network and launched an integrated distribution management system to enable enhanced control over network and system performance, reliability, and resilience.

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City of Tallahassee, Florida Full-Scale Implementation of Automated Demand Response - FINAL REPORT

July 2015

The City of Tallahassee's Automated Demand Response project involved deployment of customer systems, load control programs, and distribution automation equipment. The City deployed an automation distribution system to the majority of its critical circuits. Enhanced distribution automation implementation also included upgrades to the outage management system, supervisory control and data acquisition system, and geographic information system. The project also improved overall system cyber security.

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San Diego Gas & Electric Company (SDG&E) Grid Communication System - FINAL REPORT

July 2015

San Diego Gas & Electric's (SDG&E's) Grid Communication System (SGCS) project involved the installation of various wireless communication systems. These systems cover targeted intelligent electronic devices on transmission and distribution poles and other electric assets. SDG∓E implemented advanced high-speed wireless communications systems, updated and expanded supervisory control and data acquisition (SCADA) capabilities, and increased the communications fiber footprint, allowing the utility to remotely monitor, communicate with, and control transmission and distribution equipment. The project made critical communications upgrades at substations and supporting telecom sites. SDG&E also expanded and optimized communications infrastructure to support smart grid initiatives while increasing system resilience.

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City of Leesburg, Florida - Leesburg Smart Grid Investment Grant Project

July 2015

The City of Leesburg's (Leesburg's) Smart Grid Investment Grant project involved city-wide deployment of advanced metering infrastructure (AMI), installation of new customer systems, and expansion of distribution automation (DA) capabilities. Leesburg enacted a consumer education program to help customers fully exploit the new devices and the energy usage information they provided. The project also automated and increased the efficiency of portions of the electric distribution system through deployment of automated voltage capacitors, intelligent electronic device (IED) controls located in new and existing feeder breakers, and automated field reclosers. A system-wide coordination and sectionalizing study was also performed.

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Knoxville Utilities Board - Knoxville Smart Grid Community Project

July 2015

The Knoxville Utilities Board (KUB) Knoxville Smart Grid Community project deployed advanced metering infrastructure (AMI) and distribution automation assets. The project achieved better power quality and reactive power management with fault current indicators and volt-ampere reactive (VAR) control at substations.

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Marblehead Municipal Light Department - Integrated AMI System with Real-Time Pricing Pilot Program

July 2015

The Marblehead Municipal Light Department (MMLD) project involved town-wide installation of a fully integrated advanced metering infrastructure (AMI) system. MMLD deployed a two-way communications network, over 10,000 AMI meters, an energy management web portal, and demand response equipment. The project also included a pilot program to assess the effectiveness of critical peak pricing (CPP) and automated in-home load management, as well as a study of consumer behavior in response to the CPP pilot.

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Southwest Transmission Cooperative Arizona Cooperative Grid Modernization Project Final Project Description

July 2015

Three electric cooperatives in Arizona joined forces together to upgrade their electric grid infrastructure: Southwest Transmission Cooperative (SWTC), Mohave Electric Cooperative (MEC), and Sulphur Springs Valley Electric Cooperative (SSVEC). SWTC provides transmission service to distribution cooperatives MEC and SSVEC. All three projects installed or upgraded communications networks and deployed or enhanced supervisory control and data acquisition (SCADA) systems or energy management systems (EMSs). SWTC upgraded the communications infrastructure of their transmission network by installing optical ground wire (OPGW) cables between several substations. SSVEC expanded their existing fiber optic communications infrastructure. MEC expanded the power line carrier (PLC)-based meter communications network as well as fiber optic and microwave radio communications between the substations and their call center. SWTC further enhanced the transmission network with microprocessor-based protective relays and equipment monitors. SSVEC and MEC jointly provided 59,745 smart meters to 59,358 customers and deployed a meter data management system (MDMS) to process and package the data to be leveraged

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Rappahannock Electric Cooperative - Smart Grid Initiative

July 2015

Rappahannock Electric Cooperative's (REC's) Smart Grid Initiative project deployed smart meters across the service territory and a supporting communications infrastructure, as well as a meter data management system (MDMS) to help manage the increased data available from the smart meters. The project also deployed distribution automation equipment, including supervisory control and data acquisition (SCADA) and automated controls on distribution voltage regulators to improve power quality, reduce line losses, and reduce operations and maintenance costs through monitoring and control of distribution voltage.

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Pacific Northwest Smart Grid Demonstration Project Technology Performance Report <br/> Volume 1: Technology Performance

June 2015

The Pacific Northwest Smart Grid Demonstration (PNWSGD), a $179 million project that was co-funded by the U.S. Department of Energy (DOE) in late 2009, was one of the largest and most comprehensive demonstrations of electricity grid modernization ever completed. The project was one of 16 regional smart grid demonstrations funded by the American Recovery and Reinvestment Act. It was the only demonstration that included multiple states and cooperation from multiple electric utilities, including rural electric co-ops, investor-owned, municipal, and other public utilities. No fewer than 55 unique instantiations of distinct smart grid systems were demonstrated at the projects&apos; sites. The local objectives for these systems included improved reliability, energy conservation, improved efficiency, and demand responsiveness. The demonstration developed and deployed an innovative transactive system, unique in the world, that coordinated many of the project&apos;s distributed energy resources and demand-responsive components. With the transactive system, additional regional objectives were also addressed, including the mitigation of renewable energy intermittency and the flattening of system load. Using the transactive system, the project coordinated a regional response across the 11 utilities. This region-wide connection from the transmission system down to individual premises equipment was one of the major successes of the project. The project showed that this can be done and assets at the end points can respond dynamically on a wide scale. In principle, a transactive system of this type might eventually help coordinate electricity supply, transmission, distribution, and end uses by distributing mostly automated control responsibilities among the many distributed smart grid domain members and their smart devices. You can download the entire report within a zip file by clicking the document image, title or download button that is below. Alternatively, you can individual chapters by clicking on the file links below.

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Qualcomm Atheros, Inc. - HomePlug Green PHY Integrated Circuit Development - Final Report

June 2015

Through this HomePlug Green Physical Layer (PHY) Integrated Circuit Development project (&quot;HomePlug&quot;), Qualcomm Atheros, Inc. (Qualcomm Atheros) developed a compliant power line communications (PLC) solution to support smart grid functionality in a wide range of equipment: advanced metering infrastructure (AMI), smart meters, smart appliances, electric transportation, and home area network peripheral devices.

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FirstEnergy&apos;s Smart Grid Investment Grant - Consumer Behavior Study

June 2015

FirstEnergy has undertaken a three-year consumer behavior study (CBS) to evaluate residential customer response to alternative inducements (experimental treatments) to alter their electricity usage during the afternoon hours of hot summer days. Work was performed under funding from a federal Smart Grid Investment Grant (SGIG). The focal point of the study was to quantify how residential customers respond to a monetary inducement, such as peak time rebate (PTR), to reduce load during pre-specified hours (events) with a day&apos;s advance notice. In addition, the study evaluated the impacts of two enabling technologies on customer response: the in-home display (IHD) and programmable controllable thermostat (PCT). Only customers identified as having central air conditioning were eligible to receive a PCT. The customers without central air were eligible to receive an IHD.

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Beacon Power Interim Technology

June 2015

Hazle designed, built, commissioned, and operates a utility-scale 20 MW flywheel energy storage plant in Hazle Township, Pennsylvania (the Hazle Facility) using flywheel technology developed by its affiliate, Beacon Power, LLC (Beacon Power). The Hazle Facility provides frequency regulation services to the regional transmission organization, PJM Interconnection, LLC (PJM), through its participation in PJM&apos;s Regulation Market (a market-based system for the purchase and sale of the Regulation ancillary service). The zero emission Hazle Facility is designed for a 20 year-life over which it is capable of performing at least 100,000 full depth of discharge cycles. To achieve its 20 MW capacity, the Hazle Facility is comprised of two hundred of Beacon Power&apos;s 100 kilowatt (kW)/25 kilowatt/hour (kWh) flywheels connected in parallel. The Hazle Facility can fully respond to a signal from PJM in less than 2 seconds. The Hazle facility was constructed in an economic development zone designated by the Commonwealth of Pennsylvania and its construction relied on local contractors and labor for completion.

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Battelle Memorial Institute Pacific Northwest Smart Grid Demonstration Final Technology Performance Report

June 2015

The Pacific Northwest Smart Grid Demonstration (PNWSGD), a $179 million project that was co-funded by the U.S. Department of Energy (DOE) in late 2009, was one of the largest and most comprehensive demonstrations of electricity grid modernization ever completed. The project was one of 16 regional smart grid demonstrations funded by the American Recovery and Reinvestment Act. It was the only demonstration that included multiple states and cooperation from multiple electric utilities, including rural electric co-ops, investor-owned, municipal, and other public utilities. No fewer than 55 unique instantiations of distinct smart grid systems were demonstrated at the projects&quot; sites. The local objectives for these systems included improved reliability, energy conservation, improved efficiency, and demand responsiveness.The demonstration developed and deployed an innovative transactive system, unique in the world, that coordinated many of the project&quot;s distributed energy resources and demand-responsive components. With the transactive system, additional regional objectives were also addressed, including the mitigation of renewable energy intermittency and the flattening of system load. Using the transactive system, the project coordinated a regional response across the 11 utilities. This region-wide connection from the transmission system down to individual premises equipment was one of the major successes of the project. The project showed that this can be done and assets at the end points can respond dynamically on a wide scale. In principle, a transactive system of this type might eventually help coordinate electricity supply, transmission, distribution, and end uses by distributing mostly automated control responsibilitiesamong the many distributed smart grid domain members and their smart devices.

score: high
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ARRA Energy Storage Demonstration Projects: Lessons Learned and Recommendations

June 2015

The American Recovery and Reinvestment Act (ARRA) of 2009 (Recovery Act) provided funding for 16 energy storage demonstration projects. The projects ranged in scope from feasibility studies and technology demonstrations to full-scale, operational energy storage plants. This investment had a signicant positive impact on the grid-connected energy storage industry. The goal of this report is to summarize the lessons learned from the ARRA projects, and to make recommendations for future Department of Energy (DOE) investments. Information for this report primarily came from three sources: a questionnaire and interview with each project team; DOE energy storage program peer review presentations; and DOE reports required as part of the ARRA project. Some lessons learned were common to many projects. Development of standards, codes and protocols specic to energy storage systems will mitigate uncertainty over code compliance, streamline permitting, and should be a priority (especially related to safety). Removal of regulatory barriers that preclude optimal operation of an energy storage system with multiple applications would immediately enable further deployment (e.g., FERC standards preclude the marketing department from reliability activities). Maturity of the approach to monetization varies substantially between applications with frequency regulation as an ancillary service leading other applications. Finally, developers focused on ramp mitigation and time shifting envision a reference plant. This reference plant would scale up from the current demonstration systems and would lead to the deployment of 50 MW-scale peaker plants.

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American Transmission Company LLC (I) Enhanced SCADA and PMU Communications Backbone Project

June 2015

American Transmission Company LLC's (ATC's) Enhanced Supervisory Control and Data Acquisition (SCADA) and Phasor Measurement Unit (PMU) Communications Backbone project deployed new fiber optic transmission communications infrastructure across the company's Wisconsin footprint. The interconnection of the new fiber segments integrated a total of 149 substations within ATC's data communications and collection networks and expanded ATC's data transfer capability. ATC enhanced the fiber optic network with satellite communication links to boost reliability across key segments of the system.

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Connecticut Municipal Electric Energy Cooperative Smart Grid Project

June 2015

The Connecticut Municipal Electric Energy Cooperative (CMEEC) smart grid project (ConnSMART Program) involved participation of four municipal utilities: Groton Utilities, Jewett City Department of Public Utilities, Norwich Public Utilities, and South Norwalk Electric and Water. The project deployed 38,598 advanced meters and made interval usage web presentment available to two thirds of advanced meter customers; the ultimate intention is to provide access to all customers with smart meters. All substations located within Groton Utilities&apos; two service territories have been fully automated. The project also developed a new business intelligence platform to improve understanding and control of wholesale power costs. In addition, small pilot programs introduced and tested voluntary time-based rates and direct load control devices.

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PJM Interconnection Synchrophasor Technology Deployment Project Final Project Description

June 2015

PJM Interconnection (PJM) and 12 of its member transmission owners deployed synchrophasor measurement devices in 85 high-voltage substations and implemented a robust data collection network to provide the necessary information technology infrastructure and wide-area monitoring and coverage necessary to support further use of advanced transmission applications. The project successfully deployed phasor measurement units (PMUs), phasor data concentrators, communications systems, and advanced transmission software applications.

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Vermont Electric Cooperative Consumer Behavior Study Year 2 Final Report

June 2015

The eEnergy Vermont Utilities are one of nine Smart Grid Investment Grant recipients nationwide that conducted research into the effectiveness of dynamic electric utility rates and information feedback technologies in changing utility customer behavior. Two of these utilities, the Vermont Electric Cooperative and Central Vermont Public Service, designed Consumer Behavior Studies to test specific electric rate structures and technology solutions within their service territories. This report addresses only the VEC study, and describes the experience that has been gained by VEC and its implementation partner, Efficiency Vermont, during the second year of the study. An interim evaluation report is available for the first year of the project on smartgrid.gov.

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Golden Spread Electric Cooperative, Inc. Smart Grid Project Final Project Description

June 2015

The Golden Spread Electric Cooperative, Inc. (GSEC) Smart Grid Project deployed advanced metering and distribution automation (DA) to 10 of its 16 member distribution cooperatives (co-ops). The deployment included a total of 88,411 smart meters. The geographic area served by GSEC and the 10 participating co-ops is large and rural in nature. Each member co-op designed and planned a project to address specific challenges and achieve benefits.

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