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151 to 175 of 1888 results are displayed.
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Technology Performance Report: Duke Energy Notrees Wind Storage Demonstration Project 2015 Final Report

November 2015

The Notrees Wind Storage Demonstration Project installed an advanced battery energy storage system (BESS) with a capacity of 36 MW/24 MWh to optimally dispatch energy production from the wind farm. Such optimization could help energy storage operators capture energy arbitrage, improve grid stability, and demonstrate renewable firming value. Additional carbon dioxide (CO2) reduction benefits could also be realized, as energy storage will eliminate the need for fossil-fuel-based secondary generation that currently supports many wind farm operations.

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Progress Energy Service Company Optimized Energy Value Chain Final Project Description

November 2015

Progress Energy Service Company"s (Progress Energy"s) Optimized Energy Value Chain project involved deployment of advanced metering and distribution automation systems. The project implemented two-way communications to allow Progress Energy to manage, measure, and verify targeted demand reductions during peak periods. New information and communications systems capture commercial and industrial (C&I) meter data for billing and future implementation of new pricing programs and service offerings. Progress Energy implemented a distribution management system, automated switching, and integrated voltage and reactive power control to reduce line losses and improve service reliability. The project also installed advanced transmission systems, including on-line monitoring equipment on key and "at-risk" transmission substations and transformer banks. In addition, Progress Energy installed 255 electric vehicle charging stations in the Carolinas and Florida service territories.

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Town of Danvers, Massachusetts - Smart Grid Implementation Program Final Project Description

November 2015

The Town of Danvers' Smart Grid Implementation Program included deployment of advanced metering infrastructure (AMI), a meter data management system (MDMS), and distribution automation (DA) technology on all thirty three circuits. Smart meters and AMI for Danvers' residential, commercial, and industrial customers support time-based rate programs and a home energy network pilot.

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City of Fort Collins Utilities Front Range Smart Grid Cities Final Project Description

November 2015

The City of Fort Collins' Front Range Smart Grid Development project involved the municipal utilities for the cities of Fort Collins and Fountain, Colorado. The project included citywide deployment of advanced metering infrastructure (AMI). AMI allowed for implementation of demand response products and pilot testing of time-based rate programs. With these devices and programs came customer education and web portal access. In addition, the project expanded distribution automation capabilities, including installation of supervisory control and data acquisition (SCADA) system-connected fault indicators and SCADA-connected remote-operated feeder switches.

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Duke Energy Business Services, LLC - Smart Grid Deployment Final Project Description

November 2015

Duke Energy Business Services' (Duke's) Smart Grid Deployment project, a part of the Duke Smart Grid Program, involved implementing advanced metering infrastructure (AMI) and distribution automation systems in five states. The project included large-scale deployments of AMI and distribution automation in Ohio and North Carolina, and smaller limited deployments of distribution automation in Indiana, Kentucky, and South Carolina. Duke also initiated pilot programs for electricity pricing, including time-of-use rates, peak-time rebates, and critical peak pricing. Customers in these pilot programs used smart thermostats, web portals, and direct load control devices to reduce their electricity consumption and peak demand.

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Coast Electric Power Association Residential Time of Use program

October 2015

Coast Electric Power Association (Coast) was organized in 1939 through a merger of two electric cooperatives (Hancock Electric and Gulf Coast Electric) in South Mississippi. We provide power to almost 79,000 rural Mississippians in Hancock, Harrison and Pearl River Counties. Our mission is "to provide our member/owners superior service and dependable electricity at the lowest possible price, and to improve the economy and quality of life in our community." Coast first began offering a Time of Use (TOU) rate in June of 2009 as an option for members to use to help control their electric bill. Implementation of this type of rate design prior to 2009 was not beneficial as our energy provider, South Mississippi Electric Power Association (SMEPA), did not have a wholesale time of use rate program in effect. The goal of a TOU rate is to reduce coincident peak demand (billed demand) thereby reducing cost of purchased power. Another benefit of a successful TOU rate is that generation capacity is reduced; therefore, future capacity additions are delayed or eliminated. Using rates as an incentive/deterrent creates a voluntary, member controlled demand management program instead of a utility controlled program. A time of use rate also creates a voluntary demand management program instead of one being forced on the consumers by the utility. Consumers are able to choose whether to pay the higher cost of energy during peak times or defer using energy when there is less demand on the generation resources. From a consumers perspective managing their electric bill on a TOU rate is as simple as changing the time they heat their water, wash dishes and wash and dry clothes. Some may even choose to be more aggressive and alter when they heat and cool their home. The rollout of our TOU program was slow as special meters had to be individually programmed to capture the necessary data. Also Coast was still manually reading meters so people had to be trained to recognize which meters were TOU as well as how to interpret the data. Another deterrent to the early TOU program was the design itself. The peak time in the wholesale rate from SMEPA was very broad to cover all possible peaking times (table 1) and the rate differential was not significant enough to encourage participation. By the end of April 2010 (pre-award) only 65 members were participating in the program.

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Pacific Gas and Electric Company Advanced Underground Compressed Air Energy Storage Project Description

October 2015

Pacific Gas and Electric Company's (PG&E;) advanced underground, compressed air energy storage (CAES) demonstration project is intended to validate the design, performance, and reliability of a CAES plant rated at approximately 300MW with up to 10 hours of storage. The CAES demonstration project is scoped to test the suitability of a porous rock formation as the storage reservoir in California, and demonstrate the technological improvements in the design of such plants. Porous rock formations are much more plentiful than the salt domes now used by the two operational plants in Alabama and Germany. If this geology is proven viable, this technology has the potential to be replicated throughout California and elsewhere in the United States. The project is also differentiated by its potential use of a new CAES plant design that is much more efficient than first generation Alabama and German designs. This project is comprised of three phases. Phase I includes site selection, reservoir testing, preliminary plant design, an environment assessment and a competitive solicitation to determine if there are interested and viable parties for plant construction, ownership and operations/maintenance. Phase I is estimated to last 4.5 years. Phase II, which includes obtaining approval to proceed with the construction and commissioning of a full CAES plant, has an estimated 6-year duration. Phase III includes operations & monitoring and is expected to occur over 2 years.

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Case Study of South Kentucky RECC's Smart Grid Investment Grant Program

October 2015

On August 6, 2009 South Kentucky Rural Electric Cooperative Corporation (SKRECC) applied for a Department of Energy Grant as part of the American Recovery and Reinvestment Act (ARRA) to install an Advanced Metering Infrastructure (AMI) system throughout our service territory. We received preliminary approval for the grant on October 27, 2009. SKRECC is a rural electric distribution cooperative organized in 1938 and is located in South Central Kentucky. SKRECC provides electric service to the counties of Pulaski, Russell, Wayne, Clinton, McCreary, Casey, Lincoln, Adair, Rockcastle, Cumberland and Laurel in Kentucky and the counties of Pickett and Scott in Tennessee. We purchase our power from East Kentucky Power Cooperative (our Generation and Transmission provider). SKRECC currently has 66,472 active accounts and maintains 6,762 miles of distribution line and 51,676 transformers supported by 150,354 poles. Residential members represent the majority of our accounts representing over 93% of the active accounts and our member density is relatively low with only 9.83 members per mile of distribution line.

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Aquion Energy Sodium-Ion Battery for Grid-level Applications Project Description

October 2015

Aquion Energy and its partners will demonstrate a low cost, grid-scale, ambient temperature sodium-ion energy storage device. The energy storage chemistry in this device uses an electrochemical couple that combines a high capacity carbon anode with a sodium intercalation cathode capable of thousands of deep discharge cycles over extended periods of time. The proposed aqueous sodium-ion technology includes the use of thicker electrodes, less expensive separator and current collector materials, and the use of benign materials for electrodes and electrolyte salts. This project will progress the work from bench-scale to pilot-scale, enabling multiple ampere-hour cells to be manufactured and assembled into test batteries. Aquion plans to site units between 10 kWh and 100 kWh capacity that have the ability to perform medium to long duration (more than 2 hours) charge and discharge functions with greater than 95 percent DC-DC efficiency. The units will be safe and environmentally benign. Testing will characterize the energy storage capacity of the units, the response to various signals, compliance with utility interconnection standards, battery and power conversion system efficiency, and effectiveness under various cycles typical of the applications being validated. Utility application-level testing will test the functionality of the unit with respect to its ability to respond to external control signals and properly interact with electric grid in carrying out relevant sequences. The pilot line will be commissioned for production at the end of the project.

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Raytheon Ktech Flow Battery Solution for Smart Grid Renewable Energy Applications Project Description

October 2015

Raytheon Ktech and EnerVault will integrate EnerVault's Vault-20 battery energy storage system (250 kW, 1 MWh) with a Helios dual-axis tracker 180 kW photovoltaic (PV) system. The system will be deployed at an agricultural site in California's Central Valley. It will store the energy generated and dispatch power to run an irrigation pump and inject energy back into the utility grid during peak times to help offset demand from a section representing 4 percent of California's electricity demand. The modularity of the system provides scalability for multi-megawatt deployments. The Vault-20 consists of electrolyte tanks and transportainers, which house stacks, pumps, control system, and power conditioning systems. Technology development will progress from 15x15 cm lab-scale cells and 20-layer stacks, to a 2-5 kW prototype system, then a 30kW alpha system, concluding with a 250 kW beta system. EnerVault plans to begin manufacturing flow battery stacks in its Northern California plant within 12 months of project completion.

score: high
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Guam Power Authority Smart Grid Project: Final Description

October 2015

The Guam Power Authority's (GPA's) Smart Grid Project involved a territory-wide deployment of advanced metering infrastructure (AMI) and integration of the AMI with an outage management system (OMS). GPA also implemented substation automation equipment including voltage regulators, fault indicators, smart relays, and transformer monitors. An energy management system was deployed to leverage the new automation assets. Customers now have the ability to install devices that assist in managing electricity use and costs, including in-home displays and home area networks.

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Detroit Edison Advanced Implementation of Energy Storage Technologies Project Description

October 2015

DTE Energy will demonstrate the use and benefits of Community Energy Storage (CES) systems to strengthen grid reliability and test the ability to integrate secondary-use electric vehicle (EV) batteries into the CES demonstration effort in their service territory at the Trinity Circuit. The performance data of the CES devices and control systems under in-service operating conditions will be analyzed and used to identify gaps and facilitate how the devices can be standardized for use across the U.S. The project will also integrate the utility-owned 500 kW solar system to the energy storage device; provide proof of concept testing for an integrated, centralized communication system; and test the use of secondary-use EV batteries as CES devices.

score: high
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Duke Energy Business Services Notrees Wind Storage Demonstration Project Description

October 2015

The Notrees Project will analyze and discern how, when integrated with wind power, energy storage can compensate for the inherent intermittency of this renewable power generation resource. Incorporating both existing and new tools, technologies and techniques, this demonstration project will provide valuable information regarding wind energy storage and serve as a model for other entities to adapt and replicate. The energy storage system will be designed and constructed using fast response, advanced lead-acid batteries configured to provide 36 MW output peak power with an energy storage capacity of 24 MWh.

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East Penn Manufacturing Co. Grid-Scale Energy Storage Demonstration Using UltraBattery Technology Project Description

October 2015

East Penn Manufacturing will design and construct an energy storage facility consisting of an array of UltraBatteryâ„¢ modules integrated in a turnkey Battery Energy Storage System (BESS). In addition to the UltraBatteriesâ„¢, the BESS will include a power conditioning system, a master programmable controller, and a battery monitoring system. The completed energy storage system will be designed to sell up to 3 MW of frequency regulation to Noble Americas Energy Solutions, a designated load serving entity within PJM. In addition to frequency regulation, the system will provide demand management services to Met-Ed during specified peak power periods. These services will provide up to 1MW for 1 to 4 hours to meet the requirements of PA Act 129. The UltraBatteryâ„¢ is uniquely suited to these applications because it was designed for High Rate Partial State of Charge cycling. The system is sized to maintain the battery"s state of charge between 70 percent and 30 percent for a maximum 40 percent depth of discharge for continuous regulation services. The UltraBatteryâ„¢ is a hybrid energy storage device that combines an asymmetric ultracapacitor and a lead-acid battery in one unit cell. The UltraBatteryâ„¢ is expected to provide the same benefits as lead-acid battery systems, such as low initial cost, full recyclability, plus increased cycle life by incorporating ultracapacitor technology within the battery. To demonstrate modularity and portability, self-contained, Containerized UltraBatteryâ„¢ System will be designed and included as a subset of this project.

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Smart Grid Technologies Cut Emissions and Costs in Ohio

October 2015

Turning lights off in empty rooms, air-drying clothes, and unplugging devices when they're not in use are three of the many well-known steps residential customers can take to conserve electricity. With its Smart Grid Demonstration Program project, named gridSMART®, American Electric Power (AEP) Ohio demonstrated technologies that improve system efficiencies and benefit the customer at the same time. The project, which began in 2010 and will end in 2014, also provided insights into how smart grid technologies can increase the reliability of electricity delivery and decrease emissions. The service area selected for the project comprised approximately 150 square miles of urban, suburban, and rural neighborhoods, and included customers in Columbus, Ohio. Within the demonstration area, AEP Ohio deployed 100,000 residential smart meters and 10,000 commercial and industrial smart meters. Additionally, the utility applied distribution automation circuit reconfiguration (DACR) and volt VAR optimization (VVO) to 58 13-kV circuits from 10 distribution stations, and 12 34.5-kV circuits from six distribution stations within the demonstration area. The result was a secure and interoperable smart grid infrastructure.

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Memphis Light, Gas, and Water Division: Implementation of Smart Grid Technology in a Network Electric Distribution System

October 2015

Memphis Light, Gas, and Water Division (MLGW) implemented smart grid technology in a network electric distribution system. The installed technologies included new intelligent relays and sensor equipment to provide remote switching at the transformer level as well as vital information to aid in the design, operation, and preventive maintenance of the complex electric system. The project deployed a communications system that facilitates the flow of real-time data from intelligent electronic devices and sensors installed in the field with MLGW's control systems.

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NV Energy, Nevada Dynamic Pricing Trial Final Report

October 2015

This report covers analysis and results of the Nevada Dynamic Pricing Trial (NDPT) operations from its formal inception of recruiting in January 2013 through the close of the two-year program on February 28, 2015. The NDPT was a set of research experiments jointly sponsored by NV Energy and the federal Department of Energy (DOE) as required by the terms of the Smart Grid Investment Grant (SGIG) that the DOE awarded to NV Energy. The NDPT design was approved by NV Energy, the DOE and by the Public Utilities Commission of Nevada (PUCN), as described in the original and subsequently amended NDPT Consumer Behavior Study Plan. NV Energy conducted the NDPT as a program for single-family residential customers called Choose When You Use. NV Energy enrolled volunteer households, and then supplied them with new time-varying rates, digital and print energy education and programmable thermostats. Every participating household had previously been on standard flat rate pricing and received either a time-of-use (TOU) rate or a TOU rate with Critical Peak Pricing (CPP) events as part of the Choose When You Use program. Some households received digital and print energy education in addition to the rate and some households also received programmable thermostats. The intent of the NDPT was to monitor and understand the household changes in electricity use that may occur in response to these treatments.

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Southern California Edison Company Tehachapi Wind Energy Storage Project Description

October 2015

The Tehachapi Wind Energy Storage Project, funded by Southern California Edison (SCE) and federal stimulus funding awarded by the Department of Energy as part of the American Recovery and Reinvestment Act of 2009, is positioned to demonstrate the effectiveness of lithium-ion battery and smart inverter technologies to improve grid performance and assist in the integration of variable energy resources. The project is based at SCE"s Monolith Substation in Tehachapi, California and includes a 32 MWh battery energy storage system (BESS) and the associated power conversion system. The project will evaluate the performance of the BESS to improve grid performance and assist in the integration of large-scale variable energy resourced generation. Project performance will be measured with 13 specific operational uses: provide voltage support and grid stabilization; decrease transmission losses; diminish congestion; increase system reliability; defer transmission investment; optimize size of new renewable-related transmission; provide system capacity and resource adequacy; integrate renewable energy (smoothing); shift wind generation output; frequency regulation; spin/non-spin replacement reserves; ramp management; and energy price arbitrage. Most of the operations either shift other generation resources to meet peak load and other electricity system needs with stored electricity, or resolve grid stability and capacity concerns that result from the interconnection of variable energy resources. SCE will also demonstrate the ability of lithium-ion battery storage to provide nearly instantaneous maximum capacity for supply-side ramp rate control to minimize the need for fossil fuel-powered back-up generation.

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Seeo Inc Solid State Batteries for Grid-Scale Energy Storage Project Description

October 2015

Seeo and its partners are demonstrating a large-scale prototype of a solid-state electrolyte lithium-ion rechargeable battery for use in Smart Grid energy storage applications. Seeo seeks to validate this technology to address the needs of Community Energy Storage Systems' small (less than 100 kW) distributed energy storage systems alongside pad-mounted and pole-mounted transformers. The battery pack is more than a 50 percent improvement in weight and energy density; has 10-15+ year operating life with 3,000-5,000 or more cycles; has no volatile or flammable components; and will be 35 percent cheaper than existing lithium-ion batteries. This approach allows independent control over mechanical and electrical properties. The cell can withstand temperatures as high as 150?C and voltages of 10 volts without incident. An independent analysis of the environmental and economic impact of battery improvement will also be conducted.

score: high
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VionX Energy Distributed Energy Storage System Project Description

October 2015

VionX Energy and its partners will apply a breakthrough technology improvement from United Technologies Corporation (UTC) to build a vanadium redox flow battery based energy storage system (ESS) for load shifting, peak shaving, and renewable system integration. The 6-10 hour battery will not degrade as quickly as lithium ion and lead acid batteries, allowing a lifetime of 20 years. The ESS is a fully integrated system that comprises energy storage, power conditioning, system control, and thermal management subsystems. Two ESSs are to be demonstrated with National Grid at locations in Massachusetts. One ESS will be integrated into a single 500kW multi-hour system installed next to a 605 kW photovoltaic (PV) array in Everett, MA and the other ESS will be interfaced with a 600 kW wind turbine at the Holy Name High School feeder in Worcester, MA. National Grid will deploy, operate, and monitor the aggregated 1MW ESS"s in their respective locations for two years.

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NV Energy Nevada Dynamic Pricing Trial Interim Report - Volume 4

September 2015

A list of appendices used in the Nevada Dynamic Pricing Trial.

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Battelle Memorial Institute Pacific Northwest Smart Grid Demonstration Project Description

September 2015

Battelle Memorial Institute is collaborating with utilities, universities, and technology partners in a Smart Grid demonstration project across five states and three climatic regions, spanning the electrical system from generation to end-use, and containing all key functionalities of the future Smart Grid. This demonstration will validate new technologies; provide two-way communication between distributed generation, storage and demand assets, and the existing grid infrastructure; quantify Smart Grid costs and benefits; advance interoperability standards and cyber security approaches; and validate new business models. More than 20 types of responsive Smart Grid assets will be tested across six regional and utility operational objectives at 15 unique distribution sites operated by 11 utilities. A base of Smart Grid technology serving more than 60,000 customers will be installed, validated, and operated. All use classes are represented in the demonstration including residential, commercial, industrial, and irrigation customers. The demonstration will develop a single integrated Smart Grid incentive-signaling approach and will test and validate its ability to continuously coordinate the responses of Smart Grid assets to meet a wide range of operational objectives. It will also be among the first to engage distributed control so that wind integration problems are mitigated. Micro-grid islanding will also be evaluated for its potential to enhance reliability for customers and relieve energy demand. Team members are committed to commercializing proven technologies.

score: high
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AEP Ohio gridSMART Demonstration Project Description

September 2015

AEP Ohio and its partners are building a secure, interoperable, and integrated Smart Grid infrastructure in Ohio that demonstrates the ability to maximize distribution system efficiency and reliability, and consumer use of demand response programs to reduce energy consumption, peak demand costs, and fossil fuel emissions. The demonstration area includes 150 square miles including parts of Columbus, Bexley, Gahanna, New Albany, Whitehall, Reynoldsburg, Westerville, Blacklick, Johnstown, Alexandria, Minerva Park, and Pataskala. This area includes approximately 110,000 meters and 70 distribution circuits. AEP Ohio will implement Smart Grid technology over 58 13kV circuits from 10 distribution stations and 12 34.5kV circuits from six distribution stations. Included in this project is a new distribution management system (GE ENMAC), integrated volt-VAR control, distribution automation, advanced meter infrastructure, home area networks, community energy storage, sodium sulfur battery storage, and renewable generation sources. These technologies will be combined with two-way consumer communication and information sharing, demand response, dynamic pricing, and consumer products, such as plug-in hybrid vehicles.

score: high
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CCET Technology Solutions for Wind Integration Project Description

September 2015

The Center for Commercialization of Electric Technologies (CCET) is demonstrating new response mechanisms to help integrate large amounts of highly variable wind generation into the ERCOT grid by utilizing better system monitoring capabilities, enhanced operator visualization, and improved load management. Improved load management includes the use of smart grid technologies at Texas facilities: Reese Technology Center in Lubbock, Mueller Development in Austin, the Harmony solar community, north of Houston and residential consumers in the Dallas-Fort Worth and Houston areas.

score: high
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Consolidated Edison Company of New York, Inc. Secure Interoperable Open Smart Grid Demonstration Project Description

September 2015

The Consolidated Edison Company of New York and its partners are demonstrating a secure, interoperable, open Smart Grid that reduces electricity demand and increases energy reliability and efficiency. The project performer, servicing New York City and its suburbs, has one of the highest load densities in the world, representing a complex and diverse test bed, including critical organizations such as Wall Street, the Federal Reserve, major medical facilities, and hubs for national and global communications. Distributed thermal and battery storage, advanced metering infrastructure, home area networks, building management systems, photovoltaics, and smart electric vehicle charging have been demonstrated. The demonstrations have illustrated how data from disparate systems are securely communicated, integrated, and displayed to the control center operator through the use of decision-aid tools, thus helping operators identify problem areas and prioritize corrective action in both normal and contingency operations. Other new technologies developed include a rules-based dashboard for operators, a risk management engine to facilitate efficient operation, a transmission decision management engine that aggregates electricity supply data, an adaptive stochastic controller, and an intelligent maintenance system. It is anticipated that the technologies listed above will be scalable across urban utility territories nationwide.

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