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Florida Power & Light Company (Energy Smart Florida)

April 2015

The Florida Power & Light Company (FPL) project, known as Energy Smart Florida (ESF), deployed advanced smart meters, distribution automation, an electricity pricing pilot, and advanced monitoring equipment for the utility's transmission system. As part of the Smart Grid Investment Grant (SGIG) effort, over three million FPL consumers received smart meters.

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Technology Performance Report - SustainX Smart Grid Program - FINAL TPR

April 2015

This project develops and demonstrates a megawatt (MW)-scale Energy Storage System that employs compressed air as the storage medium. An isothermal compressed air energy storage (ICAES) system rated for 1 MW or more will be demonstrated in a full-scale prototype unit. Breakthrough cost-effectiveness will be achieved through the use of proprietary methods for isothermal gas cycling and staged gas expansion implemented using industrially mature, readily-available components. The ICAES approach uses an electrically driven mechanical system to raise air to high pressure for storage in low-cost pressure vessels, pipeline, or lined-rock cavern (LRC). This air is later expanded through the same mechanical system to drive the electric motor as a generator. The approach incorporates two key efficiency-enhancing innovations: (1) isothermal (constant temperature) gas cycling, which is achieved by mixing liquid with air (via spray or foam) to exchange heat with air undergoing compression or expansion; and (2) a novel, staged gas-expansion scheme that allows the drivetrain to operate at constant power while still allowing the stored gas to work over its entire pressure range. The ICAES system will be scalable, non-toxic, and cost-effective, making it suitable for firming renewables and for other grid applications.

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Costs and Benefits of Smart Feeder Switching - Quantifying the Operating Value of SFS

March 2015

To demonstrate the value of implementing the Smart Grid, NRECA has prepared a series of single-topic studies to evaluate the merits of project activities. The study designs have been developed jointly by NRECA and DOE. This document is the initial report on one of those topics, Smart Feeder Switching, based upon the progress of the activity to date.

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New York Independent System Operator, Inc. New York State Capacitor/Phasor Measurement Project Final Project Description

March 2015

In the New York State Capacitor/Phasor Measurement Project, the New York Independent System Operator, Inc. (NYISO) and its eight transmission owner (TO) subrecipients deployed phasor measurement units (PMUs), phasor data concentrators (PDCs), and smart grid enabled capacitors. These devices provide the NYISO with enhanced transmission grid monitoring capabilities for the New York Control Area (NYCA). Project participants also deployed new software to assist in determining real-time grid stability margins.

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National Rural Electric Cooperative Association Enhanced Demand and Distribution Management Regional Demonstration Final Technical Report

March 2015

The National Rural Electric Cooperative Association (NRECA) organized the NRECA-U.S. Department of Energy (DOE) Smart Grid Demonstration Project (DE-OE0000222) to install and study a broad range of advanced smart grid technologies in a demonstration that spanned 23 electric cooperatives in 12 states. More than 205,444 pieces of electronic equipment and more than 100,000 minor items (bracket, labels, mounting hardware, fiber optic cable, etc.) were installed to upgrade and enhance the efficiency, reliability, and resiliency of the power networks at the participating co-ops.The objective of this project was to build a path for other electric utilities, and particularly electrical cooperatives, to adopt emerging smart grid technology when it can improve utility operations, thus advancing the co-ops" familiarity and comfort with such technology. Specifically, the project executed multiple subprojects employing a range of emerging smart grid technologies to test their cost-effectiveness and, where the technology demonstrated value, provided case studies that will enable other electric utilities - particularly electric cooperatives - to use these technologies.

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NSTAR Electric Company - Grid Self-Healing and Efficiency Expansion

March 2015

The NSTAR Electric Company (NSTAR) Grid Self-Healing and Efficiency Expansion project involved deployment of two-way communications infrastructure and distribution automation (DA) equipment on 400 circuits. New switches, sectionalizers, reclosers, and condition monitors were installed to enable automatic detection and isolation of power outages, followed by rapid restoration of functional portions of the circuits.

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Midwest Independent Transmission System Operator Midwest ISO Synchrophasor Deployment Project Final Project Description

March 2015

For this project, the Midwest Independent Transmission System Operator (Midwest ISO) deployed synchrophasor technology throughout its service footprint. The project deployed phasor measurement units (PMUs), phasor data concentrators, and advanced transmission software applications. This technology has increased grid operators visibility into bulk power system conditions in near real time, enabled earlier detection of conditions that could result in grid instability or outages, and facilitated information sharing with neighboring regional control areas.

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Load Impact Analysis of Green Mountain Power Critical Peak Events, 2012 and 2013

February 2015

This report summarizes results from a two-year Consumer Behavior Study (CBS) executed by Green Mountain Power (GMP) as a component of the eEnergy Vermont Smart Grid project. The purpose of this study was to understand and compare two different types of electricity pricing structures: Critical Peak Pricing (CPP) and Critical Peak Rebate (CPR; also known as the Peak Time Rebate), both of which are intended to provide incentives for residential electricity customers to reduce demand during peak hours. In addition the study sought to identify the additional value of In-Home Display technology in reducing peak hour and monthly electricity consumption.

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Technology Solutions for Wind Integration in ERCOT

February 2015

Texas has for more than a decade led all other states in the U.S. with the most wind generation capacity on the U.S. electric grid. The State recognized the value that wind energy could provide, and committed early on to build out the transmission system necessary to move power from the windy regions in West Texas to the major population centers across the state. It also signaled support for renewables on the grid by adopting an aggressive renewable portfolio standard (RPS). The joining of these conditions with favorable Federal tax credits has driven the rapid growth in Texas wind capacity since its small beginning in 2000. In addition to the major transmission grid upgrades, there have been a number of technology and policy improvements that have kept the grid reliable while adding more and more intermittent wind generation. Technology advancements such as better wind forecasting and deployment of a nodal market system have improved the grid efficiency of wind. Successful large scale wind integration into the electric grid, however, continues to pose challenges. The continuing rapid growth in wind energy calls for a number of technology additions that will be needed to reliably accommodate an expected 65% increase in future wind resources. The Center for the Commercialization of Electric Technologies (CCET) recognized this technology challenge in 2009 when it submitted an application for funding of a regional demonstration project under the Recovery Act program administered by the U.S. Department of Energy1. Under that program the administration announced the largest energy grid modernization investment in U.S. history, making available some $3.4 billion in grants to fund development of a broad range of technologies for a more efficient and reliable electric system, including the growth of renewable energy sources like wind and solar. At that time, Texas was (and still is) the nations leader in the integration of wind into the grid, and was investing heavily in the infrastructure needed to increase the viability of this important resource. To help Texas and the rest of the nation address the challenges associated with the integration of large amounts of renewables, CCET seized on the federal opportunity to undertake a multi-faceted project aimed at demonstrating the viability of new smart grid technologies to facilitate larger amounts of wind energy through better system monitoring capabilities, enhanced operator visualization, and improved load management. In early 2010, CCET was awarded a $27 million grant, half funded by the Department of Energy and half-funded by project participants. With this funding, CCET undertook the project named Discovery Across Texas which has demonstrated how existing and new technologies can better integrate wind power into the states grid. The following pages summarize the results of seven technology demonstrations that will help Texas and the nation meet this wind integration challenge.

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Painesville Vanadium Redox Flow Battery Project American Recovery and Reinvestment Act (ARRA)

February 2015

The City of Painesville and Ashlawn Energy, LLC, undertook to build a one-megawatt, eight-hour, Vanadium Redox Flow Storage Battery under Department of Energy (DOE) Cooperative Agreement DE-OE0000233 for installation at the Painesville Municipal Power Plant in Painesville, Ohio. The financial February 1, 2010 assistance award initially provided $8,767,258.00 in funding, with $3,743,570.00 federal share, and $5,023,688.00 in recipient cost share. On November 15, 2010, the agreement was amended to reflect $9,462,623.00 in total funding, increasing federal share to $4,243,570.00 and recipient cost share to $5,219,053.00. As of this writing, total federal share expended is $4,193,609.41. Total non-federal cost share contribution is $4,578,728.99. It was anticipated that the Painesville battery project would receive project matching funds from the state of Ohio under the Ohio Air Quality Development Authority Advanced Energy (OAQDA) forgivable loan program. After a change in Administration, Ohio's state priorities changed resulting in the states withdrawing funding for all OAQDA Advanced Energy projects, including the matching funding needed for this project in Painesville, OH. A technology license was obtained from the inventor of the vanadium redox flow battery (VRFB), Dr. Maria Skyllas-Kazacos (University of New South Wales, Australia). The City of Painesville contracted with Ashlawn Energy, LLC to manage the development and fabrication of the battery as well as to prepare and provide all reporting to DOE. Ashlawn developed its supplier base, which included InnoVentures LLC, Concurrent Technologies Corporation (CTC), and others to build components and conduct prototype testing. The City of Painesville contracted for and had built a new 4,900 square foot Butler building to house the battery at the site of its Municipal Power Plant at a cost of $432,828 using city funds as contribution included as part of project cost share. A number of prototype VRFB stacks were built and tested at CTC working up to a full sized 10,000 watt stack. Five patents were applied for improvements to the VRFB made by Ashlawn Energy engineers, and are currently pending at the USPTO. A drawing package, schedule, vendor selection, and economic business model was completed.

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Hazle Spindle, LLC Beacon Power 20 MW Flywheel Frequency Regulation Plant Project Description

February 2015

Beacon Power will design, build, and operate a utility-scale 20MW flywheel plant at the Humboldt Industrial Park in Hazle Township, Pennsylvania for the plant owner/operator, Hazle Spindle LLC. The plant will provide frequency regulation services to grid operator PJM Interconnection. The Beacon Power technology uses flywheels to recycle energy from the grid in response to changes in demand and grid frequency. When generated power exceeds load, the flywheels store the excess energy. When load increases, the flywheels return the energy to the grid. The flywheel system can respond nearly instantaneously to an independent system operator"s control signal at a rate 100 times faster than traditional generation resources. The system does not burn fuel and has zero direct emissions. The Beacon Gen4 flywheel is designed to provide 100 kW of output and store 25 kWh of energy. Two hundred flywheels will be connected in parallel to provide 20 MW in capacity and can fully respond in less than 4 seconds. The plant can operate at 100% Depth of Discharge with no energy degradation over time and provide unlimited cycles for most applications. The flywheels are built to last 20 years or more. Virtually no maintenance is required in the mechanical portion of the flywheel system. Flywheel technology has been successfully tested on live grids at scale power in New York and California. The technology achieved system availability of over 97 percent, higher than the average for conventional generators performing frequency regulation. It is currently deployed at a megawatt scale under New England"s Alterative Technologies pilot program, and a 20 MW plant in New York Independent System Operator (ISO) territory in Stephentown NY.

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Pecan Street Smart Grid Demonstration Program - Final Technology Performance Report

February 2015

This document represents the final Regional Demonstration Project Technical Performance Report (TPR) for Pecan Street Inc.'s (Pecan Street) Smart Grid Demonstration Program, DEOE-0000219. Pecan Street is a 501(c)(3) smart grid/clean energy research and development organization headquartered at The University of Texas at Austin (UT). Pecan Street worked in collaboration with Austin Energy, UT, Environmental Defense Fund (EDF), the City of Austin, the Austin Chamber of Commerce and selected consultants, contractors, and vendors to take a more detailed look at the energy load of residential and small commercial properties while the power industry is undergoing modernization. The Pecan Street Smart Grid Demonstration Program signed-up over 1,000 participants who are sharing their home or businesses electricity consumption data with the project via green button protocols, smart meters, and/or a home energy monitoring system (HEMS). Pecan Street completed the installation of HEMS in 750 homes and 25 commercial properties. The program provided incentives to increase the installed base of roof-top solar photovoltaic (PV) systems, plug-in electric vehicles with Level 2 charging, and smart appliances.

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Advanced Distribution Management Systems

February 2015

Today, a number of utilities are implementing advanced distribution management systems (ADMS), a software platform that integrates numerous utility systems and provides automated outage restoration and optimization of distribution grid performance. In effect, ADMS transitions utilities from paperwork, manual processes, and siloed software systems to systems with real-time and near-real-time data, automated processes, and integrated systems. The report provides practical advice to assist utilities in deploying an ADMS including insights on making the business case, defining requirements and selecting a vendor, preparing the data, integrating systems, and governing the project.

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Insights into Advanced Distribution Management Systems

January 2015

The American Recovery and Reinvestment Act (ARRA) of 2009 spurred investments in smart grid technology and programs at utilities across the country. The Smart Grid Investment Grant program and Smart Grid Demonstration projects that it funded provided unprecedented opportunities to learn from smart grid implementation. In 2011, the U.S. Department of Energy, Office of Electricity Delivery and Energy Reliability (DOE OE), in partnership with electric utilities that received ARRA funds, convened a series of Regional Smart Grid Peer-to-Peer Workshops. These were designed to bring together utilities to engage in dialogues about the most compelling smart grid topics in each region. The meetings offered a platform for smart grid implementers at all stages of project deployment to share their experiences and learn from each other. Realizing the benefits of bringing utilities together to share their experiences, in February 2014 DOE OE formed the ADMS Working Group by assembling a leadership team of representatives from the utility industry with the mission to collect the experiences, insights, and lessons learned from implementing these systems. This guide is the result of a one-day meeting held at CenterPoint Energy in Houston, Texas, in May 2014 that was followed by a series of conference calls about specific aspects of ADMS, interviews with individuals leading ADMS projects at their utilities, and a final small group meeting at San Diego Gas & Electric in California in October 2014. The information in this guide came directly from the people in the industry on the leading edge of transforming their distribution systems. Although the working group included more than 40 people and represented 30 utilities and organizations, the following were key contributors of their experience: San Diego Gas & Electric (SDG&E;) CenterPoint Energy (CPE) Austin Energy Duke Energy Kansas City Power & Light (KCP&L;) Pacific Gas & Electric (PG&E;) We hope that sharing this information will help other utilities overcome or avoid some of the challenges these first adopters identified and be able to deploy their own ADMS successfully and efficiently.

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Lakeland Electric Consumer Behavior Study Interim (Year 1) Evaluation Report

January 2015

This interim evaluation report summarizes results from the first year of the Lakeland Electrics two-year 3-Period Time of Use (TOU) program called Shift-to-Save (STS). Lakeland Electric has undertaken this study as part of a full system wide deployment of advanced metering infrastructure (AMI) funded in part by a grant from the U.S. Department of Energys (D.O.E.) Smart Grid Investment Grant (SGIG) Program. Lakelands submission to the D.O.E. listed the objectives of this study to include estimating the following: the amount of peak demand savings, the amount of load shifting from on peak to off peak periods and from shoulder periods to off peak periods, and the amount of net overall electric usage savings to customers. Other objectives included assessing customer acceptance and retention, and assessing customer volunteer rates verses assigned rates, as well as customer dropout rates.

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Costs and Benefits of Conservation Voltage Reduction - CVR Warrants Careful Examination

January 2015

To demonstrate the value of implementing the Smart Grid, NRECA has prepared a series of single-topic studies to evaluate the merits of project activities. The study designs have been developed jointly by NRECA and DOE. This document is the initial report on one of those topics, Conservation Voltage Reduction, based upon the progress of the activity to date.

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COMMUNICATIONS: The Smart Grid's Enabling Technology

January 2015

To demonstrate the value of implementing the Smart Grid, NRECA has prepared a series of single-topic studies to evaluate the merits of project activities. The study designs have been developed jointly by NRECA and DOE. This document is the initial report on one of those topics, Communications, based upon the progress of the activity to date.

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Interoperability of Demand Response Resources Demonstration in NY

January 2015

The Interoperability of Demand Response Resources Demonstration in NY (Interoperability Project) was awarded to Con Edison in 2009. The objective of the project was to develop and demonstrate methodologies to enhance the ability of customer sited Demand Response resources, both conventional and renewable, to integrate more effectively with electric delivery companies. In order to achieve the project objective, interoperability between the delivery company and the demand response resources had to be achieved. The electric delivery company does not actively control these demand response resources, thus through this project the interoperability was demonstrated, by integrating the operations of a demand response service provider (DRSP), a large multi-facility retail customer (RC), and a delivery company (DC). The electric delivery company in this project, Con Edison, is dedicated to lowering costs, improving reliability and customer service, and reducing its impact on the environment for its customers. These objectives also align with the policy objectives of New York State as a whole. To help meet these objectives, Con Edison's long-term vision for the distribution grid relies on the successful integration and control of a growing penetration of distributed resources, including demand response (DR) resources, and distributed generation (DG). The Interoperability Project provides an example of how these demand response resources can be integrated into the operations of the utility and the value of these resources and their integration to customers. The project focused on four main components; the Demand Response Command Center (DRCC), the incremental Building Control Unit (IBCU), the Thermal Storage Plant (TSP) and the Virtual Generator (VirG). An analysis of the customer benefits of the VirG and the TSP are displayed later in the report along with the architecture and a set of protocols had to be developed associated with the DRCC and the IBCU to enable secure integration with the customer sited resources. All of these components were designed and configured to provide value to both the electric delivery company and the customer. The project ultimately showed that customer sited demand response resources can successfully be integrated into electric delivery company operation.

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Data Guard Energy Data Privacy Program: Voluntary Code of Conduct Concepts and Principles

January 2015

This document is the result of a 22-month multi-stakeholder effort that was facilitated by the Energy Department's Office of Electricity Delivery and Energy Reliability (DOE) in coordination with the Federal Smart Grid Task Force. The Voluntary Code of Conduct (VCC), which has now been branded as the DataGuard Energy Data Privacy Program, will provide companies with a consumer-facing mechanism for demonstrating their commitment to protecting consumers¹ data and thus increase consumer confidence.

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Los Angeles Department of Water and Power Smart Grid Regional Demonstration Interim Technology Performance Report

January 2015

The Department of Energy (DoE) awarded the Los Angeles Department of Water and Power (LADWP) funding for a Smart Grid Regional Demonstration Program (SGRDP) in response to DoE Federal Opportunity Announcement DE-FOA-0000036. The LADWP is collaborating with its project partners to carry out this demonstration on the designated areas to include two university campuses – the University of California, Los Angeles (UCLA) and the University of Southern California (USC) – surrounding neighborhoods, City of Los Angeles facilities, and LADWP power system test labs, to:Develop and demonstrate innovative SG technologies;Identify sociological and behavioral factors essential for SG technology adoption by utility customers;Quantify costs and benefits of these technologies.The last project partner, Jet Propulsion Laboratory (JPL), is responsible for the Cyber Security aspects of the project.It is hoped that the SGRDP will help open the market for viable, commercially available SG solutions, representing the state of the industry such that similar large-scale SG infrastructure projects can be implemented across the nation.This Report provides insight into the implementation, operation, and analytical progression of demonstrated technologies. Many of the observations in this Report are preliminary while LADWP continues to refine impact trends and conclusions. Since LADWP undertook numerous smart technologies simultaneously, data and interpretation adjustments are anticipated as the technologies evolve.

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PECO Smart Future Greater Philadelphia Final Project Description

January 2015

PECO's Smart Future Greater Philadelphia project included installation of a robust, multi-tiered communications infrastructure to support deployment of advanced metering infrastructure (AMI)and distribution automation (DA). Over 784,000 smart meters were deployed, as well as a meter data management system (MDMS), a web portal, a time-of-use (TOU) pricing pilot, and a variety of DA assets, including capacitor and voltage controllers.

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Idaho Power Company (IPC Smart Grid Program)

December 2014

Idaho Power Company (IPCs) Smart Grid Program included deployment of advanced metering infrastructure (AMI), AMI enabled customer systems, and advanced synchrophasor monitoring equipment for the transmission system. IPC installed 380,928 smart meters for residential and commercial customers and deployed a web portal to provide customers with access to their AMI data and new energy management tools. Smart meters enable IPC to enhance its offering of existing time of use rates to customers and further reduce peak loads on the system. Peak load is also managed through direct load control devices on participating customers irrigation systems. IPC also installed phasor measurement units (PMUs) to improve the diagnostic capabilities and overall reliability of the transmission system. In addition, the company developed tools to enable the effective integration of renewable resources onto the transmission grid.

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City of Wadsworth (Connected Grid Project)

December 2014

The City of Wadsworth's (Wadsworth's) Connected Grid project involved system wide deployment of advanced metering infrastructure (AMI) and targeted installation of in-home displays(IHDs), home area networks (HANs), programmable communicating thermostats (PCTs), and load control devices. Wadsworth also upgraded and expanded its deployment of distribution automation(DA) equipment across 17 circuits, including installation of automated reclosers (feeder switches) and capacitor bank controls.

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Pacific Northwest Generating Cooperative (Advanced Meter Infrastructure Implementation Project)

December 2014

The Pacific Northwest Generating Cooperative (PNGC) project is a collaborative effort between nine distribution cooperatives that implemented advanced metering infrastructure (AMI) solutions. Project teams deployed energy management web portals, meter data management (MDM) systems, two-way communications infrastructure, and 97,013 smart meters.

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Perfect Power Prototype for Illinois Institute of Technology

December 2014

The Renewable and Distributed Systems Integration (RDSI) Program within the R&D; Division of the Office of Electricity Delivery and Energy Reliability, Department of Energy sought to develop and demonstrate new distribution system configurations integrated with distributed resources. The smart grid program supported by the American Recovery and Reinvestment Act of 2009 (ARRA) aimed at modernizing the nations electric energy system and significantly affecting utility investments in the electric power sector, thereby contributing to job creation and preservation and economic recovery. These efforts are critical to achieving the nations ambitions for renewable energy development, electric vehicle adoption, and energy efficiency improvements. Starting in October 2008, Illinois Institute of Technology (IIT), in collaboration with over 20 participating members, led an extensive effort to develop, demonstrate, promote, and commercialize a microgrid system and offer supporting technologies that will achieve Perfect Power at the main campus of IIT. A Perfect Power system, as defined by the Galvin Electricity Initiative (GEI), is a system that cannot fail to meet the electric needs of the individual end user. The Principle Investigator of this Perfect Power project was Dr. Mohammad Shahidehpour, Director of the Robert W. Galvin Center for Electricity Innovation at IIT.

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