Executive Summary The distribution sensor market is currently in a high-growth phase, and the growth of this market will continue over the next five years. Utilities will increasingly deploy distribution sensors and increase their overall investment in sensors. IOUs will continue to make the largest investments in distribution sensors. The U.S. market will remain the largest market for distribution sensors over the next five years, and China will not be too far behind.

Key Findings

Analysts believe that changes to the distribution system will be revolutionary, while changes to the transmission system will be evolutionary in nature. Because the distribution system is less advanced, it will receive more initial focus and investment.

Over the next three years, utilities in North America, Europe and Asia Pacific will drive the growth of the distribution sensor market. In 2012, North America accounted for 39% of the distribution sensor market, while Europe and Asia Pacific accounted for 30% and 20%, respectively. In 2017, North America’s and Europe’s share will drop to 34% and 25%, respectively. Asia Pacific’s share will increase to 27% in 2017.

Many utilities which started their Smart Grid projects in 2010, are just now (in 2013 or 2014) starting to deploy distribution assets. Among these utilities, their spending on distribution monitoring system technologies will likely not kick-off until 2015 or 2016.

From 2012 to 2021, the U.S market value for distribution sensors is projected to grow from $1.56 billion to $6.60 billion. During this time period, the market is projected to grow by 17.4% annually.

More than 27 different sensor types are used in smart grid applications, the largest number of them being smart meters (wireless), and power load monitoring and balancing sensors. However, new sensors are likely to be developed for various existing and new applications. Line rating and wireless sensors are expected to be used extensively.

Many new players will enter the distribution sensor market, thus leading to an overall decrease in sensor prices.

Fiber optic sensors are in use in only 10% of all U.S. However, utilities are slowly getting more comfortable with deploying fiber optic sensors.

The potential size of the utility advanced sensor market is massive, as worldwide Smart Grid deployment would include billions of sensors.

Emerging Smart Grid Trends

Throughout the 1990s, satisfied with reliability improvements, U.S. utilities significantly reduced spending on distribution infrastructure from 5.7 percent of revenues in the 1980s to 3.5 percent in the 1990s. The result: a $57 billion gap in spending that the American Society of Civil Engineers has said needs to be filled by the end of the decade to replace outdated, aging equipment.

In the past, Distribution Automation consisted mainly in automatic operations, conducted by autonomous IEDs/controls, such as fault location, isolation and service restoration and voltage regulation. Today, advances and falling prices of the communication and control technologies, which can be embedded in the distribution grid and used for monitoring and remote control of various major distribution equipment, such as switches, capacitors banks, reclosers and voltage regulators, bring along a list of new automated Smart Distribution applications.

According to the IEEE PES Smart Distribution Working Group (SDWG) the following applications can generally be identified to Smart Distribution:

Remote controlling of feeder reclosers and switches, Automatic feeder reconfiguration based on remote control of reclosers and switches

(includes fault detection), Fault detection (distribution feeder devices), Fault location (accurate) based on waveform analysis, Capacitor bank control, Volt & VAR control using sensors on the feeder, Power Quality measurements (harmonic content), Distribution overhead grid monitoring (power measurements), and Distribution underground grid monitoring and control.

The current U.S. Administration has intensified interest in alternative sources of energy and the environmental impact of all energy sources. Utilities have responded to this interest and have become involved in several test projects across the nation. However, the long-term test rests upon the financial payoff that can be demonstrated for sensors, both in the transmission and distribution of electricity. A general trend in the U.S. is the increasing reliance on electricity for everyday living, and intolerance for loss of that electricity. Particularly, the younger generation expects uninterruptible power for every electronic device. And as the U.S. shifts to electric vehicles, the demand for more electricity will increase. Probably, the best opportunities for replacing or installing new sensors will occur when utilities upgrade their inadequate electricity infrastructure and when utilities are building new infrastructure to meet increasing demands. Thus, in the U.S., effective sensor marketing will have to rely upon financial payback, particularly in today’s economy, as each utility evaluates its individual needs. In the near term, the types of sensors that utilities will likely require would measure PMU, voltage, and current to enable fault detection, voltage optimization, and transformer monitoring.

Deployment of sensors in the grid has been notoriously lacking for many years, especially in the distribution segment. Putting more of them into the grid will be essential to increasing the efficiency of the electricity power infrastructure, which itself is essential at a time of long-term rising prices for electricity. In addition, more sensors help meet the growing demands from regulators and consumers for more grid reliability at a time when this reliability is challenged by everything from cyber terrorists to the need to integrate highly fluctuating renewable energy sources.

Utilities worldwide have identified the potential benefit of a grid-wide deployment of advanced sensors. Advanced sensors provide utilities with real time feedback about grid conditions, such as temperature, pressure, voltage, and phase. This information then allows utilities to make informed decisions to optimize grid operations. When combined with other technology, advanced sensors enable self-healing abilities, allowing the system to automatically address maintenance issues without requiring operator intervention. As many utilities are completing smart meter rollouts, they are considering other, lower cost ways to optimize their energy grid. Advanced sensors offer an attractive option, as they typically are

deployed at a shorter ROI, and offer the ability to monitor and manage a wide variety of devices located at critical junctures throughout the grid.

The distribution line sensor market is currently in a high-growth phase. This growth of this market will continue over the next five years. Utilities will increasingly deploy distribution sensors and increase their overall investment in sensors. IOUs will continue to make the largest investments in distribution sensors. The U.S. market will remain the largest market for distribution sensors for the next five years. However, China will not be too far behind.

Sensors that can provide the most functionality at the best price will ultimately win over utilities. Further, utilities will continue to demand more uses and data to be provided from distribution line sensors. Such demand will leave little room for low-end solutions among progressive utilities. That said, developing countries could certainly deploy low-end sensors at a high rate given the budget constraints associated with utilities in the developing world. Scalable and interoperable sensor solutions will be best positioned for market penetration as utilities will need to ensure sensors can integrate with future systems that can collect and process more data.

The International Electrotechnical Commission has also created ISO/IED 14543-3-10 to address energy-harvesting technology in wireless devices. The standard supports a battery free sensor and establishing policies on its development. Since energy harvesting and wireless technology are two very popular trends in advanced sensor development, this standard will govern the future of smart sensor development.

Market drivers, such as an aging global electrical system, smart grid policy and deployment targets, renewable energy targets, and an increased focus on customer service, will all play a significant role in driving the demand for distribution sensors. Additionally, several key trends impacting utilities, such as IT/OT integration and cyber security, will further influence sensor adoption and the capabilities utilities seek from sensor providers.

Drivers

Demand Drivers of Sensors and Sensor SoftwareDriver Description & Sensor/Software Impact

Aging Electrical Infrastructure

Across the developed and developing world, electrical distribution systems are outdated and costly to maintain. Sensor information and data will allow utilities to better track and asses the power quality and overall condition of the system.

Federal Smart Grid Policies/Targets

Many countries such as the U.S., EU, China, Japan, South Korea, Brazil, and Japan have set aggressive targets for smart grid deployments and investments over the next five to ten years. Sensing has been identified as an integral component of the smart grid ecosystem of technologies. This fact means that sensor demand will follow overall demand for smart grid technologies.

Renewable Integration Polices/Targets

Globally, countries have made a commitment to increase their energy generation from renewable sources such as wind and solar power systems. Renewable integration will require utilities to optimize their assets and system data to ensure a seamless flow of renewable power is delivered to their customers. Sensors and sensor analytics will play key role in this transition.

Increase Power Quality/Customer Service

Customer satisfaction is becoming a larger part of the overall utility value proposition as it relates to increasing profits and shareholder value. Energy systems of the future will be driven by customer markets rather than regulators. This transition may take 10 to 15 years to materialize, but it is a factor that must not be overlooked. Sensors can

increase the overall reliability and power quality of distribution systems, thus reducing system downtime and customer complaints.

Trends

Trends Influencing Sensor Adoption Driver Description Sensor/Sensor Software Impact

IT/OT System Integration

Increasingly, utilities are integrating information technology and operations technology systems to better optimize their assets and to leverage the information being provided from grid connected devices. IT/OT integration will demand sensor data and software technologies that can be integrated into third party systems such as an ADMS, OMS, or MDMS.

Cyber security

Cyber security has become a top priority for major utilities across the globe. There is no doubt that it will be a hot button issue for the immediate future. Sensors and sensor software providers will have to ensure the security of their solutions can thwart cyber-attacks. Utilities will also want to know that none of the physical equipment is comprised during the manufacturing process.

Advanced Analytics – Big Data

Levering data is a major trend in the utility world. The volumes of data, especially from sensors, can yield new visualization tools and offer preventative features that were not available to grid operators a few years ago.

Predictive and Preventive Systems

Real-time data and analytics from sensors, coupled with third-party system integration, will allow utilities to develop advanced monitoring and predictive features that allow them to significantly mitigate system disturbances. Such technology will lead to reduced maintenance costs and increased customer satisfaction.

The Importance of Distribution Sensors and the Major Sensor Needs Among Utilities

The use of distribution sensors is of vital importance to the utility industry. They result in:

Reduced costs Greater power reliability Averting peak load need Reducing likelihood of disruptions Enabling “self-healing” responses Enabling electric vehicle use and energy storage options Real-time reporting of line faults More efficient outage management Reporting different electricity measurements

Zpryme conducted an internet survey concerning sensor issues in April of 2013 and received responses from 125 utility professionals.

The utility survey revealed that the top six needs for distribution line sensors or monitoring systems were: measure current (87.1%), fault identification and fault location (61.4%), power quality monitoring (52.9%), measure current and voltage (45.7%), renewables interconnect monitoring (35.7%), and Volt/Var control (32.9%).

In addition, respondents reported that their primary deployment plans involve sensors on overhead distribution lines (69.3%). Additionally planned deployments include indoor applications (40.0%), underground cables in dry vaults 38.6%, and underground cables in wet vaults requiring submersible sensors (20.0%).

Regulatory Landscape

Worldwide governmental policies encouraging advanced sensor deployment originated mainly with policies to encourage energy efficiency and reduce greenhouse gas emissions. For example, the European Union’s 20/20/20 plan aims to reduce greenhouse gas emissions by 20% through incorporating 20% renewable energy generation into the energy mix by 2020. Although advanced sensor deployment is not explicitly included, advanced sensors enable such changes and are essential to reaching this goal. Many countries have also encouraged smart meter deployment. All smart meters contain advanced sensor technology, which allows the two-way transfer of information with utilities about consumption and grid

conditions. In fact, the global deployment of smart meters will include over 1.5 billion devices, and achieve 55% market penetration by 2020. This deployment will install smart sensors throughout the grid. Much of the regulations governing smart sensors have been established through regulations regarding smart meters, such as security and privacy issues, communication frequencies, and restrictions. In addition, smart meter policies worldwide have also set up goals of self-healing capabilities and real time communication to both inform the utility about grid conditions and consumption, and allow consumers to conserve energy.

In the United States, the Energy Policy Act of 2005 indirectly encouraged active sensor deployment by setting goals for time-based pricing and demand response, as well as offering consumers pricing information so that they could control consumption. The EPAct was very proactive through encouraging advanced sensor deployment in smart meters. The act is also expected to set the tone for further regulations, including the incorporation of smart sensors and measurements to create a more efficient and reliable grid.

A number of individual States are seen as pioneers in overhauling the utility regulatory process:

The Massachusetts Department of Public Utilities (DPU) has ordered the state’s electric distribution utilities to file long-term plans to modernize the grid over a ten year period.

Hawaii’s PUC’s proposals represent one of the most dramatic overhauls of the utility regulatory process undertaken since utility regulation was established in the early 20th century. Potential regulatory mechanisms that could stimulate utilities to better enable Hawaii’s energy transition include incentives to encourage the acceleration of retirements of fossil generation, ceasing development of new generation resources or undertaking major modifications to existing units rather than maximizing current potential generation resources, and unbundling ancillary services to provide price signals for alternative sources of supply.

On April 24, 2014 the New York Public Service Commission (PSC) announced a proposal called Reforming the Energy Vision (REV). It seeks to change the way the state’s electricity is procured, distributed, and regulated. The REV’s goal is to reconfigure utility regulation to promote energy efficiency, increase the penetration of renewables and grow distributed energy resources. The PSC proposes a new model wherein utilities will plan and operate the distribution grid, integrating distributed energy resources and providing a market where consumers can optimize their energy generation, management and delivery options. Utilities will assume a role as Distributed System Platform Providers (DSPP) acting as the interface between customers and the bulk power system.

The state of Minnesota already has strong energy efficiency standards, as well as an ambitious renewable portfolio standard that calls for 30% of electricity from renewables by 2030. As it looks forward, Minnesota expects to see a future in which customers produce all or part of their own power, want more control over how that power is generated (e.g. green energy), and want more information and control over when where and how they use energy. To prepare for this new future, Minnesota has conceived the e21 Initiative. It will convene a broad set of stakeholders over a year to reexamine the utility business model and regulatory framework. GREAT Plains Institute is partnering with Xcel Energy, Minnesota Power, Center for Energy and Environment (CEE), George Washington University Law School, and other stakeholders to map out the transition to a regulatory model in Minnesota that:

Stabilizes rate impacts and provides competitive, equitable, and transparent rates.

Aligns utility and customer interests with the pursuit of Minnesota’s goal of an 80% reduction in GHGs by 2050 and the transition to a sustainable, carbon-neutral energy system.

Provides for economically-viable utility business model(s) that supports energy efficiency, renewable energy, distributed generation, and advanced energy technologies.

Provides for a reasonable rate of return for utilities and other energy producers and a fair allocation of costs for all customer classes, with as few stranded assets as possible during the transition.

Better aligns state and federal authority in light of the changing nature of the electric energy system and the increasing interstate character of utilities.

Better coordinates processes and markets for infrastructure development across

transmission, generation, distribution and storage technologies. Reduces regulatory administration costs and resources (e.g., results in fewer rate cases or

otherwise reduces the burden of the regulatory process).

Distribution Sensors

Sensors in the distribution system automatically measure and communicate equipment characteristics that are related to the "health" and maintenance of the equipment. These characteristics can include, but are not limited to temperature, dissolved gas, and loading. These devices can automatically generate alarm signals if conditions exceed preset thresholds. Also included are network sensors that deliver signals and information between distribution automation devices, networks, other sensors, and between these devices and utility grid control systems. These networks can utilize wired or wireless connections, and can be utility-owned or provided as services by a third party.

Distribution line sensors can be placed on overhead distribution lines, in indoor applications, and underground cables. They are used to measure current, voltage, and for Fault Detection, Isolation and Restoration, and power quality monitoring.

FDIR technology incorporates fault detection, isolation, and restoration of power to customers. Today, most distribution grids in the U.S. lack sensors and rely upon a trouble call system in which customers report outages to the utility. A fully automated FDIR system would require an entire network of interconnected intelligent devices (which could incorporate optical fiber). Such FDIR systems are decades away from being fully implemented within the U.S. The technology will dictate the use of the following types of sensors:

Distribution sensors measure current, voltage, temperature (in substations), harmonic distortion, vibration, and wind. The difference between transmission line sensors and distribution sensors is the location of those sensors. Distribution sensors are located much closer to the end user.

Optical sensors represent the newest technology available for measuring the entire spectrum of electricity fault indicators (temperature, current, vibrations, strain, etc). Optical sensors are advantageous because they are immune to electrical and magnetic interference, are small size, light weight, passive (all-dielectric), have high temperature performance, have large bandwidth, have high sensitivity, are

environmentally rugged, and have the ability of distributed sensing. Because optical sensors have digital potentiality, they can be readily linked to modern communication systems like the internet and cellular phones.

Smart voltage/current sensors are the Smart Grid’s answer to traditional regulators that are installed today on transmission lines at substations. These cumbersome electromechanical regulators are likely to be supplanted by smart voltage sensors with integrated communication back to the substation. These devices will enhance efficiency in the grid by constantly monitoring conditions to the end of the distribution lines. In addition, voltage, current and continuity sensors will help pinpoint outages thereby creating a proactive system where sensors automatically report outages and automated switching re-routes. Sensors can also provide outage isolation information to vastly improve the time to restore service.

The table below defines emerging sensors, which include advanced sensors, wireless system sensors, and intelligent electronic devices (IEDs) and sensors. Optical fiber sensors and distribution system sensors are also described.

Sensor Definitions, Location of Use and Purpose

Sensor Type Definition

Primary Location of

Use Main Purpose

Emerging sensors: Advanced Sensors

Advanced sensing and measurement technologies will acquire and transform data into information and enhance multiple aspects of power system management. These technologies will evaluate equipment health and the integrity of the grid. They will support frequent meter readings, eliminate billing estimations, and prevent energy theft. They will also help relieve congestion and reduce emissions by enabling consumer choice and demand response and by supporting new control strategies.**

25% transmission

75% distribution(for 2012)*

Power factorPower quality throughout the gridPhasor relationships (WAMS)Equipment health and capacityMeter tamperingVegetation intrusionFault locationTransformer and line loadingTemperatureVoltageGas sensingCurrent

Emerging sensors: Wireless systems sensors

Wireless systems sensors are networks of nodes that sense and potentially also control their environment. They communicate the information through wireless links enabling interaction between people or computers and the surrounding environment. The data gathered by the different nodes is sent to a sink which either uses the data locally, through for example actuators, or which is connected to other networks. Sensor nodes are the simplest devices in the network.

Sensor networks monitor the functioning and the health of grid devices, monitor temperature, provide outage detection and detect power quality disturbances. Control centers can thus immediately receive accurate information about the actual condition of the grid.

20% transmission

80% distribution(for 2012)*

Health of grid devicesOutage detection and power quality disturbancesTemperatureVoltageGas sensingCurrent

Emerging sensors: Intelligent Electronic Devices and Sensors

Intelligent Electronic Devices (IEDs) and sensors placed throughout the power system to monitor conditions in real time. In particular, sensors in substations and transmission corridors.

75% transmission

25% distribution(for 2012)*

Power quality throughout the gridEquipment health and capacityMeter tamperingVegetation intrusionFault locationTransformer and line loadingTemperatureVoltageGas sensingCurrent

Optical Fiber Sensors

Fiber-optic-based current and potential sensors, accurately measure voltage and current to revenue standards over the entire range of the device. Fiber-optic, temperature-monitoring system: Provides direct, real-time measurement of hot spots in small and medium transformers, thus addressing utility concerns about the safety and reliable operation of high-voltage equipment. Use of optical fiber sensors used to remotely sense physical quantities such as strain, temperature, vibration and electric current.

60% transmission

40% distribution(for 2012)*

TemperatureVibrationVoltageStrainGas sensingCurrent

Distribution Sensors

Sensors in the distribution system that automatically measures and communicates equipment characteristics that are related to the "health" and maintenance of the equipment. These characteristics can include, but are

Distribution system (100%)

TemperatureVoltageHealth of grid devices

not limited to temperature, dissolved gas, and loading. These devices can automatically generate alarm signals if conditions exceed preset thresholds. Also included are network sensors that deliver signals and information between distribution automation devices, networks, other sensors, and between these devices and utility grid control systems. These networks can utilize wired or wireless connections, and can be utility-owned or provided as services by a third party.

Outage detection and power quality disturbances

Key Players

Varentec

Varentec is a Menlo Park, a CA start-up company backed by ARPA-E and Khosia Ventures and focused on applying digital power electronics to help manage power. The company was awarded a $2.2 million grant by the DOE in 2010, a $5 million ARPA-E grant in 2011, and a $7.7 million Series A round in 2012 from investors which include Khosia Ventures.

On July 28, 2013, the company released a volt/VAR control device called “ENGO” (Edge of Network Optimization). It combines a line sensor which is hung on a power line with a hot stick with the capability to alter line voltages by injecting the right amount of VARs at the right place at the right time, using power electronics and analytics that constitute the company’s intellectual property. Because each one is a sensor, a network of ENGO devices can send back lots of power quality data for a traditional DMS to use. At the same time, each device is programmed to make autonomous decisions on how to affect the line it sits on and can respond very rapidly at the local level. A distinguished feature is the ability to flatten voltages along far-off sections of distribution line, all while managing dynamic fluctuations like solar panels rising and falling in power output as clouds pass overhead.

Varentec is currently working with 3 major utilities. 2 of them are in the US and thought to be Southern Company and the National Rural Electric Association (NRECA), as well as the Mexican state-owned utility Comision Federal de Electricidad.

GridSense

GridSense, an Acorn Energy company, is very active in this space and is formulating forward-looking plans to expand their offerings. The company has been making sensors for the power grid since 1974 and is currently engaged in integrating advanced sensing and measurement capabilities with remote communications and computing technologies. Their grid solutions improve the efficiency and operation of all the critical points along the electricity delivery system.

Their “LineIQ” product is an out-of-the-box overhead line fault indicator and monitoring solution for network lines up to 138 kV which is upgradable via a simple firmware download. The core of the system is a self-powered sensor easily installed (hot stick) on energized lines which enables the continuous capture of critical performance data, including true voltage measurement, fault direction, fault waveform, load profile, power factor, line status and condition, ambient and conductor temperature, and time-stamped event recordings. The GridSense Communications Gateway supports both solicited and unsolicited reporting, and allows wireless, remote data retrieval via cellular, Ethernet, mesh radio, Wi-Fi and more. Data can also be retrieved on an on-site laptop via a wireless connection with the GridSense LocalLink with has a range up to 150 feet.

Cooper Power Systems (Now Eaton)

Cooper Power Systems, a subsidiary of Cooper Industries, PLC, is part of the electrical business of Eaton. Eaton acquired Cooper Industries, PLC in late 2012. The company is a leading provider of engineering optimization and modeling tools, and in general, maintains a complete portfolio of products and services required to transform, protect, connect, and build out an electric power system backbone. They provide a comprehensive array of smart apparatus including smart sensors, voltage regulators, capacitors, reclosers, switchgear and controls, all of which can be integrated with enterprise level software and secure communications. Reliability and grid-point solutions include integrated volt/VAR Control, feeder, and substation automation systems, and endpoint solutions include AMI and DR.

Cooper Power System’s “Outage Advisor” sensors locate and communicate passage of a fault, whether temporary or permanent. The sensors also prevent false indications due to inrush and capacitive discharge currents and send daily health reports with 24 hour load profiles. The product uses energy harvesting technology to combine the sensor and RTU into one easy to install sensor without the need for an external RTU or secondary power.

ABB (Ventyx)

At a recent DistribuTech conference, ABB Medium Voltage Distribution Components unveiled a new 15kV current and voltage sensor line trademarked with the name “DistribuSense”. The sensors are designed to be used in a variety of smart grid applications including volt/VAR Optimization, conservation voltage reduction and fault detection, isolation and restoration.

The ABB DistribuSense current and voltage sensors provide easy integration with recloser, overhead switch, capacitor bank and distribution transformer devices giving utilities a full range of sensor capabilities to meet any application where additional grid visibility is beneficial. They can also serve as independent sensing points for radial or loop scheme circuits to monitor voltage levels or dynamic loads.

There are several sensor models. The first, known as WLS-110, is a current and voltage combination sensor primarily designed to address efficiency problems that utilities may have with excessive reactive power.  The combination of current and voltage allows a capacitor controller to detect the level of VARs on the system.  The volt/VAR software can then adjust the capacitors in the most efficient manner. The WLS-110 has a 120V output on the voltage side and the current output is 1A so that they can be used with the widest number of smart meters, relays and capacitor controllers.

The KLS-110 can be used as a current only sensor. It has the same form as the combination sensor without the voltage sensing functionality.

The VLS-110 is a voltage only sensor used either with reclosers or as a stand-alone application for distribution grid voltage sensing.  The VLS-110 has a 120V output that will work with a wide variety of distribution devices.

For utilities who cannot afford the cost of upgrading a substation, ABB offers an “Intelligent Data Sensor technology” solution. This technology allows a utility to automate its electromechanical substations without the high cost of a microprocessor panel upgrade. By attaching a clamp-on AC/DC sensor to the relay wires and connecting its Cat5 cable to the supplied recording switch, real-time analog and digital information is readily available for analysis. The clamp-on sensor, coupled with ABB’s waveform data analysis, is capable of fast line restoration, fault and disturbance analysis, and real time monitoring of evolving loads.

ABB is well known for its openness to form collaborative relationships. Following this tradition, ABB and Elster have integrated Elster's ALPHA-based medium voltage AGInode monitoring and communications platform with ABB's split-core combination voltage and current sensor. The integrated product will provide remote wireless feeder monitoring at the medium voltage level. Data gathered from the medium voltage sensing points can be combined and time-synchronized with other system-level data allowing utilities to more efficiently monitor and operate their distribution network. This offering provides utilities with a cost-effective solution for plug-and-play metering of overhead medium voltage feeders. It can be integrated into existing SCADA infrastructure or into Elster's EnergyAxis communications system.

ABB and Elster are also working together on a wide range of other solutions for the Advanced Grid Infrastructure (AGI) Initiative. Among the commercially available and planned offerings are combined voltage/current MV sensors with EnergyAxis-enabled Smart Meters, as well as innovative solutions for CVR, loss detection and reporting, integrated volt/VAR control, FLIR, and on-line power flow.

On March 27, 2014, ABB won an order from ACEA (Azienda Comunale Elettricità e Acque), the Italian utility, to supply medium voltage products that will facilitate the development of a pioneering smart grid project spanning a new section of Rome's electrical distribution network. As part of the order, ABB will supply its state-of-the-art UniSec switchgear equipped with protection relays from the Relion product family. This extremely compact switchgear has specifically been developed for smart grid applications and has combined current and voltage sensors for use in secondary substations. It also includes devices for primary substations and for interfacing with distributed generation in secondary distribution substations for better reliability and availability.

Tollgrade Communications

Tollgrade Communications, Inc. was acquired by Golden Gate Capital, a San Francisco-based private equity firm for a reported value of $137 million in 2011. The company was voted by Smart Grid News readers as one of 2013's Smart Grid Companies to Watch, the only pure-play sensor company to make the cut.

Tollgrade offers a product called “LightHouse”, a real-time distribution monitoring solution providing utilities enhanced Predictive Grid intelligence for better visibility into their network. LightHouse consists of inductively powered snapped-on medium voltage sensors deployed in the field that measure load current, fault current, electric field strength, power factor, phase angle, sags, surges, wire temperature and harmonics, as well as predictive analytics software distributed over the network.

The company’s sensors have much lower power requirements than many competing devices, down to 3 amps, as compared to a more standard 25 amps or so. That allows them to be placed farther down feeder lines where there’s less current.

As new applications and smart-grid technologies are introduced into the grid, software analytic modules and remote software updates of sensors are easily sent over-the-air, making LightHouse a deployed solution that can last and adapt to the distribution network for at least the next 15 years.

In April of 2014, Tollgrade announced the availability of the company’s LightHouse Medium Voltage (MV) Power Sensor, the first all-in-one line sensor for monitoring voltage and current that requires no

calibration, batteries or additional pole mounted equipment. The hot stick deployable, inductively-powered voltage sensor measures voltage with a 0.5% accuracy.

The company has a 50 hertz version of its LightHouse medium voltage sensors available in Europe and Asia, and Western Power Distribution in the United Kingdom is the company’s first European installation. In addition, Tollgrade Communications announced on April 14, 2014 that Veridian Conncections, a utility that provides electricity distribution services to more than 116,000 customers located in nine municipalities across east central Ontario, deployed their LightHouse platform that includes integrated medium voltage smart grid sensors and sensor management system software with predictive grid analytics.

Lindsey Manufacturing

Lindsey Manufacturing is an anomaly in this space. They are a privately owned family business, highly respected in the electric utility industry, and have been designing, engineering and patenting innovative T&D product solutions since 1947.

In an effort to provide economical devices to accurately measure current and voltage in remote locations, Lindsey Manufacturing has created a complete line of overhead and underground current and/or voltage insulated sensors for distribution protection and automation applications up to 46kV and 600A. The overhead sensors encompass five styles or models and can be retrofitted to existing equipment or built into new equipment: Standard Voltage Monitoring Insulators (SVMI’s) are used on a team of three reclosers to determine the location of a fault and to automatically reconfigure the feeder. Substation/Switchgear CVMI’s are used on air break and vacuum bottle switches and for SCADA in substations; Bus Bar style CVMIs and Voltage Sensing Standoff Insulators are used in conjunction with an SF6 switch; Clamp Top CVMIs are for monitoring feeders with 1% current and voltage accuracy; and a Multicore Sensor which eliminates the need to cut the conductor or make a jumper through a tube. The company also provides Underground Elbow Sense Current & Voltage Monitors.

CURRENT GRID (now Ormazabal)

In March of 2013, Ormazabal, a Spain-based Velatia company, acquired CURRENT GRID to leverage CURRENT’S three lines of business, all key parts of future electrical networks, into their product offerings: smart metering solutions, low and medium voltage network monitoring and analysis systems, and products for communications networks. The extensive international organization of Ormazabal will promote the introduction of CURRENT solutions in countries where Ormazabal has a strong sales network, such as Germany, France, the United Kingdom, China and Latin America.CURRENT’S sensing and analytics solutions portfolio directly improves grid reliability while providing grid intelligence and alerting into utility software systems such as SCADA, DMS, and volt/VAR solutions.

The company provides a low-voltage sensor/analyzer (LVA) which is installed on distribution transformers to deliver real-time data about current voltage, power and energy measurements, as well as advanced power quality measurements, such as THD and harmonic analysis. By analyzing the collected data at the edge of the network, CURRENT’S LVA solution provides real-time event and alarm intelligence that gives utilities insight into the health of the transformer which enables them to proactively improve the efficiency and reliability of the distribution grid and support the integration of distributed renewables and EVs. In addition, CURRENT’S LVA optionally provides integrated support for WAN backhaul communications and routing utilizing 3G cellular or WiMax technologies. By combining

support for metering, advanced sensing, and WAN communications, utilities can significantly reduce CAPEX and OPEX costs when deploying an AMI.

CURRENT also provides a medium-voltage underground sensor/analyzer which was specifically designed for US-style underground MV feeders. It analyzes current measurements and provides real-time URD fault location detection and notifications. This solution also supports transformer health by monitoring voltage conditions on the LV side of the network.

In addition, CURRENT offers Rogowski coil sensors in a variety of sizes. These current (amp) sensors can be used on single low-voltage cables to bundles of larger cables. They highly reject external magnetic fields and automatically calibrate when connected to an LVA, a solution which eliminates the on-site calibration often required with current transformer solutions.

GE

GE Energy provides a vast array of advanced distribution automation and grid monitoring products and solutions.

The road which led GE to their current smart grid portfolio was marked by numerous acquisitions along the way. One of the benefits of GE’s much heralded $200 million Ecoimagination Challenge of 2010 was the company’s acquisition of one of its grid challenge winners, FMC-Tech, an Irish power line monitoring company. FMC-Tech fits cables with sensors that can measure current and conductor temperature and can send that real-time information to a controller that then sends it back to the utility via a cellular connection. FMC-Tech solutions are a key component of a utility’s distribution automation system which provides information on locating faults, providing dynamic line ratings and helping manage maintenance and repair crews. The system is designed to easily integrate with SCADA, EMS, DMS and OMS systems.

GE Energy built a network of intelligent line sensors (FMC-T6) for customers in Europe that gather power transmission and distribution data such as current and voltage, temperature and line sag. The GPS-synchronized sensors sit directly on the line and beam the data wirelessly to computer servers via an on-board 2.4 GHz radio. The sensors measures critical parameters of the overhead lines and conduct time synchronized samplings to enable a wide area analysis of network events and characteristics. Math and software algorithms are applied to the input to alert utilities about bottlenecks, line failures, and other problems on the grid, all the while providing the benefits of focusing on a line’s load profile, monitoring consumption, and detecting power theft. The Multilin technology enables utility workers to monitor the entire system from computer screens inside a control room or to pull it up on their smart phones. So far, GE has rolled out the technology in Poland, Ireland, and the UK, and the company is seeing interest from around the world.

Sentient Energy

Sentient Energy is a privately-held company founded in 2009 and backed by venture capital from Foundation Capital. Since their inception, the company has gained a lot of attention from the industry. In 2010, Sentient was one of 12 winners splitting $55 million from GE’s Ecomagination Challenge, and in 2012, GTM Research named Sentient one of its runners-up on its “Smart Grid Players to Watch” list. It has earned a reputation for its low-cost grid sensor technology and its deep partnership with Silver Spring Networks.

Sentient aims to provide utilities with lower deployment costs than competing grid sensors by attaching their sensors to the wires they are going to monitor, and then drawing its power from the line itself. The company’s “Master Monitor 2“ (MM2) sensors generate their own power from the electro-magnetic field around the conductor, A primary design criterion of the MM2 was the ability for a single field worker to install and activate the line monitor with minimal effort using traditional hot-stick methods. As such, no RTU, secondary power connection or pole attachment is required. Although there are a few other companies using similar inductive powering technologies for their grid sensors, Sentient also has a battery backup to cover times when the power goes out which is a very important consideration for fault detection. In addition, through an industry partnership with Silver Spring Networks, the sensors are available with SSN’s radios inside. For its part, SSN is reselling the MM2 sensors and has enhanced its “GridScape” network management application to support Sentient’s devices across the breadth of its deployments. Integrating line-powered devices into an existing network could be about a third less expensive than competing systems. Industry experts have speculated that the combined capabilities of these companies result in a per sensor cost of approximately $500.

Another core product offering is Sentient’s “Advanced Monitoring Platform” (AMP) which is comprised of MM2 and MM3 line monitoring devices, upgradable firmware applications and the “AMPLE” enterprise software suite. MM2 and MM3 line monitors are integrated field monitoring, computing and communications devices developed for medium voltage distribution networks. Each unit contains multiple sensors for operating and fault current, voltage characteristics (MM3 only), as well as line and ambient temperature measurement. Both MM2 and MM3’s have high-resolution current and voltage (MM3) waveform capture capabilities and built-in communications. Acting as the sensing and monitoring device for numerous Sentient analytics modules, the AMP master monitors use Sentient’s patent-pending IBOLT power harvesting technology to continuously monitor line operating conditions and events such as real-time current and ampacity, voltage presence and characteristics (MM3), faults, momentary outages and equipment-related disturbances. The units are powered for unlimited availability and stay connected during outages which enable immediate power restoration. Master Monitor computing capabilities feature on-device storage and a fully programmable controller running Linux-based applications. The devices can process captured data locally, analyzing waveform events and data trends ranging from milliseconds to years in duration. Master Monitors communicate key grid event information in real time and provide detailed supplemental information upon operator request.

Another of these is “Log-I”, a detailed load profiling monitor which measures load and conductor temperature at either preconfigured intervals or as values change, based on parameters set by the user. This information is delivered through the line monitor’s integrated communications system. Log-I can be used anywhere the utility needs to collect accurate load and temperature profile data from inside the Substation fence to the edges of the distribution system and everywhere in between.

The third is “Waveform”, a wave monitor which is an optional high-resolution waveform capture application available on the Master Monitor 2 device. It captures waveform data associated with faults or other network events and transmits them wirelessly, as needed, over the AMI or DA network. Waveforms can be analyzed locally against a library of known waveform “signatures” or communicated back to the utility for storage and further analysis in the AMPLE enterprise software suite. Waveform data is stored in the AMPLE indefinitely and can be useful in forensic studies of outages, device failures and proactive maintenance analysis.

The MM2 and MM3 can also perform all these functions simultaneously in a single device with new functions becoming available as application offerings expand. In addition, each Master Monitor can be

hardware configured to serve as a relay/repeater for mesh and other communications networks as part of the company’s “Master Mesh Relay” family of products.

Siemens

Utilizing the newest in low-power sensor technology, Siemens provides “SICAM FCM”, an elaborate fault locator used to judge distribution network health conditions for MV and LV applications, especially for compensated and isolated networks. It monitors the capacity utilization of distribution network components, and measures more than 100 values, including r.m.s. values of voltages (phase-to-phase and/or phase-to ground), active and reactive currents, power and energy factors, phase angles, harmonics of currents and voltages, total harmonic distortion per phase plus frequency and symmetry factors, energy output, as well as external signals and states. Independent settings for these variables can be programmed to trigger on settable limits. In the event a violation of these limits occurs, the unit generates alarms, and up to 6 alarm groups can be defined using “AND/OR” for logical combinations.

Echelon

Echelon offers an innovative software-hardware combo to control the distribution portion of the grid wherein their smart meters function as smart sensors. They work in conjunction with the company’s Control Operating System (COS) software. Smart meters from Echelon and from its Open Smart Grid Protocol (OSGP) meter partners worldwide can now be upgraded in the field to function as multi-parameter grid sensors. These meters are the industry’s first smart meters that separate billing data from grid power quality data because they are read on independent time cycles. By separating these data types, the utility can collect relevant power quality information, such as voltage, frequency and power factor, on an as-required basis, instead of collecting large volumes of billing and operational data from each meter on every read cycle.

Echelon’s smart meters now communicate using power line networking, which sends information over the same lines that conduct electricity, a fact that allows Echelon to pick up information on voltage and frequency that wireless-based solutions might have to add extra sensors to get at. However, Echelon intends to support a host of wireless connections for ECoS and its ECNs, including industry-standard 900-megahertz systems.

Echelon has also developed an approach to address the grid’s edges. Their plan is to place “Edge Control Nodes” at the low-voltage transformers that typically serve as the final step-down point between the local grid and end users, and link them up with their CoS software platform. These sensors and controls could cut the 5 percent or so of power lost to distribution grid inefficiencies every year, and will be critical to helping manage increasing numbers of rooftop solar panels, plug-in electric or hybrid vehicles, and other new technologies being installed at the grid’s edges.

The company’s technology, which is open to third-party application developers, will be significantly important as smart grids scale to incorporate more users, more distributed generation, and other applications such as street lighting and EV charging. Duke Energy has proven its interest in this type of technology by being the first US utility to place an initial order with Echelon to the tune of $14.5 million, a figure that could grow to up to $150 million.

S and C Electric

S&C’s staunch position in the smart grid space is unusual in that the company is employee-owned. S&C has a vast arsenal of products and equipment to address nearly every aspect of the grid, but the company

is currently most recognized for its broad DA offering in the form of its “IntelliTEAM SG” Automatic Restoration System. The system uses advanced controls, network communication, and distributed intelligence to quickly isolate a fault and then restore service to the maximum amount of load possible. Although S&C is a smaller player in the field, this equipment-software-distributed intelligence product combination is presenting serious competition to behemoth companies such as ABB, Siemens and GE.

The company asserts on their web site that the basic building block of IntelliTeam SG is a “team”, a line segment bounded by up to eight automatically controlled switching/fault-interrupting devices. The “team” monitors real-time voltages and currents using sensors integrated into the switching/fault-interrupting devices, each of which is configured to know its normal role in the system, its name (DNP address), and other key settings such as maximum capacity and normal switch function. Information on currents, voltages, loading data, etc. is then transferred between “teams”. Using the voltages and currents measured at the switching/fault-interrupting devices, along with the configuration settings, IntelliTeam SG will identify the location of a fault anywhere in the system. The fault will be automatically isolated to the one affected “team” by opening the switching/fault-interrupting devices in conjunction with the source-side protective devices. Once the fault has been isolated, IntelliTeam SG will seek out all possible power sources, to restore service to as many “teams” as possible, as quickly as possible. Before closing a switching/fault-interrupting device to restore service, the system automatically verifies that the alternate source will not be overloaded, by adding the pre-fault load of the de-energized segment to the present real-time load of the alternate source. Restoration is typically completed in seconds.

IntelliTeam SG can automate systems of any size and manage any number of alternate sources and loads within the constraints of circuit loading. Although IntelliTeam SG does not require a SCADA master station to function, it fully supports master control. SCADA can be used to control when IntelliTeam SG is active and when it’s not.

IntelliTeam SG works in conjunction with S&C overhead and underground switching and protection equipment including “IntelliRupter PulseCloser”, “Scada-Mate Switches” and “Scada-Mate CX Switches, remote supervisory PMH and PME pad-mounted gear and remote supervisory ”Vista” underground distribution switchgear. But IntelliTeam SG isn’t limited to use with S&C products. With S&C’s “IntelliNode” Interface Module, IntelliTeam SG’s interoperability extends to a wide array of new and existing DNP 3.0-compatible intelligent electronic devices applied with conventional reclosers, as well as the switching devices of other manufactures, including SEL overcurrent relays, Nu-Lec and Cooper recloser controls, GE’s feeder management relays and ABB’s protection relays.

In October of 2012, S&C announced the latest generation of their IntelliTeam volt/VAR Optimization System (‘VV”). As a result of this software release, IntelliTeam VV can work with a broader range of equipment, and the enhanced platform now supports 240-volt systems, which are used in Europe and Australia. It offers real-time control and works seamlessly with automatic reconfiguration systems which make it an effective solution for improving grid performance. The VV system helps utilities increase overall energy efficiency by improving power factor and reducing voltage across the distribution system, ultimately achieving greater reductions in peak demand and energy usage. The new features allow utilities to create voltage zones where multiple grid devices can be grouped as an independently configurable zone, as well as voltage buffers that are configurable for automatic calculation and adjustment. In addition, the software offers reporting on communication devices. It also enables Conservation Voltage Reduction (CVR), which allows utilities to lower voltage levels at the end user while still meeting power quality requirements, thus eliminating the waste associated with running system voltage conservatively high.

S&C’s “Vista” underground distribution switchgear systems have also garnered some prominent attention. In 2010, Cemig Distribuição SA tendered a bid for 450 underground distribution switches, devices that can shift power from one circuit to another in the medium-voltage grid, with the specification that they had to be flood-proof. The utility had manually operated underground circuit switches in places that they wanted to automate. The tender also included the utility’s desire to connect to sensors to track everything from transformer loads and faults to attempted theft, a big problem in Brazil. S&C proposed to add both automation and sensor capabilities to the vaults where these devices sit, and hook them up to an existing fiber network. The plan included connecting their devices to motion detectors to sense intrusion, as well as temperature sensors and, power quality monitors. S&C won the $38.5 million contract to install its Vista Underground Distribution Switchgear systems across Cemig’s territory, including the soccer stadium in Belo Horizonte that will host games during the 2014 World Cup, as well as urban and rural territories across the state of Minas Gerais. Other grid equipment vendors make gear that can run while submerged in water but most of that equipment requires separate communications connections and those control systems are rarely made to run underwater. Although it did cost a bit more to make sure the connections to Cemig’s fiber network were leakproof, S&C put all of it together in a single waterproof package.

Schweitzer Engineering Laboratories, Inc. (SEL)

Schweitzer Engineering Laboratories, Inc. (SEL), also an employee-owned company, designs and manufactures products and services for the protection, monitoring, control, automation and metering of electrical power systems, including the T&D, renewable energy and communication segments. Many of SEL’s products already have the communications and control capabilities necessary to make the grid smarter and more secure, including transformers, reclosers and communication solutions. A wide range of the products also feature additional smart grid applications such as synchrophasors, interoperability, distribution fault location and integrated metering. SEL sees the emergence of synchrophasors as a technology that can be a game changer at both the transmission and distribution levels. They have equipped some of their distribution products with PMUs, including their relays and reclosers.

SEL created the first digital relay in 1984 and has continued as a leading innovator ever since. During this period of longevity, SEL has earned, and maintained, long-term utility relationships which affords them the ties that are required to focus research and development investment into clients’ needs. Although digital relaying is the staple of SEL’s core business, promising automated restoration systems enabled with the SEL’s “Mirrored Bits” communications protocol have reached restoration speeds rivaled by few in the industry.

The company’s Fault Indicator and Sensor Division designs, manufactures and supplies fault indicators and sensors to utilities around the world. All of the products are applied to the overhead lines with a hot stick. They offer a number of sensing products for overhead lines, including “AR360 AutoRANGER Fault Indicators”. The AR360 Fault Indicators are equipped with a sophisticated microprocessor which senses and measures load and detects faults on lightly loaded line with as little as 50A of current. The AR360 steps up its trip threshold as load increases to remain secure through 1200A loads. A distinctive rotational ultra bright flash sequence displays fault location with 360 degrees of visibility. Faults start a red-amber alternating flashing sequence that appears to rotate around the device. After two minutes, the microprocessor checks for voltage and load current to determine if the fault was temporary or permanent. Permanent faults cause the red-amber sequence to continue. Temporary faults switch the flashing sequence to amber only.

SEL also provides a Wireless Sensor (“WSO”) for overhead lines. The DA sensor employs the AutoRANGER technology described above and monitors average load current, ambient temperature, fault

threshold, battery status, and history of outages and surge events. Reports are transmitted to an access point on a communications network using an integrated radio which operates in conjunction with a utility’s existing communications infrastructure, such as a mesh or other radio network. SEL has also released a second generation of the product, “WSO-11”. It stores peak load data as it monitors the distribution line for loss of current and faults. Used in existing systems to speed fault location, the WSO-11 may be applied in conjunction with the distance-to-fault element in the protective relay to determine the location of the fault when multiple distance-to-fault estimations are present. Installation near remotely controlled motor-operated switches will provide information for feeder reconfiguration. To aid the rapid restoration of power, the sensor employs an inrush restraint feature that coordinates with automated reclosing schemes. It also offers a target display on each sensor as a visual tool to help guide line crews to the fault. The WSO-11 can be programmed remotely over the air. This feature allows settings changes and firmware upgrades throughout the entire system of sensor installations, and network operators can modify sensor settings to accommodate special application needs without leaving their desks.

SEL is known for being open to partnering with second-tier vendors to add flexibility to other vendor solutions. The company is one of the partners in Xcel Energy’s SmartGridCity project and has also delivered successful solutions to ComEd (improving distribution reliability for wireless networks) and the Mexican Comisión Federal de Electricidad (providing smart load shedding with synchrophasor solutions). During 2010, SEL cooperated with On-Ramp Wireless to conduct a field test connecting wireless sensors throughout a western utility’s 200-square-mile distribution grid which included mountainous terrain. In the test, SEL’s WSO’s were joined with a fully integrated On-Ramp “Ultra-Link Processing” (ULP) wireless communications system. The results of the field test showed that wireless sensors can be successfully connected throughout the distribution grid, significantly cutting the time needed to isolate, repair and restore electric service to customers in a distribution network.

In 2012, SEL announced the release of new capabilities in the “SEL-651R Advanced Recloser Control” that improve reliability and communications for distribution automation. New ethernet communications allow users to integrate the SEL-651R into either ethernet or serial-based communications networks with standard DNP3 or Modbus protocols. The SEL-651R also has an option for IEC 61850. Ethernet provides another high-speed option for faster fault detection, isolation, and restoration. To improve system operation, the product includes synchrophasor capability for applications such as phase identification, islanding detection of distributed generation, and wide-area monitoring, protection, and control. The SEL-651R is ideal for distribution automation applications with six voltage inputs for both source-and load-side voltage sensing. SEL has also added a built-in web server to the SEL-651R for convenient, read-only access to basic recloser control information, such as settings, metering, status, and event history data, as well as for the secure, remote uploading of firmware. In addition to the new communications features, the new 60-cycle-length event reports and faster sampling rate of 128 samples per cycle provide better event analysis. There is also an additional 48 Vdc power supply option for substation applications. The product is compatible with a wide range of recloser manufacturers, including ABB, Cooper, G&W, Hawker Siddeley, Joslyn, Tavrida, Thomas & Betts, and Siemens.

SEL also offers what is called the BEACON Field-Programmable Timed Reset (“BTRIP”). It is designed for overhead system applications in the voltage range of 4160V to 69kV. A super bright flashing LED display provides a clear indication of an overcurrent event and is completely powered by a long life, high-capacity lithium battery that provides 2100 typical flash hours. The BTRIP is available in five program selection choices, each containing four field-selectable trip values. Utilities can specify which program settings they wish to have factory set, or they can select/change the trip value in the field using SEL’s “CRSRTT” tool.

SEL offers a similar variety of fault indicators for underground distribution applications. The “RadioRANGER” Wireless Fault Indication System reduces the need to access vaults to retrieve FCI status. SEL fault indicators equipped with magnetic RadioRANGER Interface Probes communicate their status to an SEL-8300 Wireless Interface. Utility personnel can retrieve subsurface FCI status at street level through wireless communication between the SEL-8300 Wireless Interface and the hand-held SEL-8310 Remote Fault Reader. The two-way communications link prevents ambiguity by transmitting both faulted (tripped) and normal (reset) status information. The wireless interface and waterproof interconnection system is rated to 15 feet submersion.

SEL’s “Test Point Reset” (TPR) fault indicators are designed to aid in fault location on underground distribution systems that use terminators having test points. TPR’s are installed on 200A or 60A separable connectors with test points.  No load current is required as the TPR’s are line-powered using the potential present on the test point of elbow terminators. They are available in single- or three-phase versions with integral or remote displays, and they automatically reset upon restoration of system voltage. All of these products and components contribute to the functionality of SEL’s “Distribution Automation Control System” (DAC). The system includes drag-and-drop configuration software on an SEL information processor. It includes the ability to automate up to 100 devices per controller and can network multiple controllers for large systems in a seamless fashion. SEL proudly issued a press release On January 14, 2013 to announce that within days of commissioning their DAC system, the Electric Power Board (EPB) of Chattanooga, Tennessee averted a widespread power outage. A fallen tree severed a power line on a 46kV looped sub transmission system, cutting power to three substations and 11,258 customers. Within seconds, the SEL DAC system isolated the faulted circuit, remotely closed two breakers, and in collaboration with an adjacent 12kV automation system, restored power to the unfaulted portions of the network.

Grid Sentry

Grid Sentry is a spin-off from Defense Research Associates which shares its Beavercreek, Ohio headquarters. DRA developed the power-harvesting equipment to draw radiated electricity from overhead wires, without harming the lines, to power cameras and sensors used in surveillance. The U.S. armed forces and civilian law enforcement agencies are DRA’s key markets for this technology. DRA developed the technology initially with funding from the Air Force Research Laboratory through the Small Business Innovation Research program that provides funding to help small companies develop technology to support Defense Department needs. Upon completion of a contract with the Air Force Research Laboratory, located at Wright-Patterson AFB, to research power-harvesting for military applications, DRA saw an opportunity to use this concept and engage in commercial markets. In October 2009, Grid Sentry, LLC was formed to license and commercialize technology developed by (DRA) to monitor and capture currents from utility sub-stations.

Grid Sentry applied to the Ohio Department of Development in March of 2011 for $400,000 in Third Frontier funding. Collaborators supporting the project include the University of Dayton’s Institute for Development and Commercialization of Advanced Sensor Technology, Dayton Power and Light Company, and Grid Sentry’s sister company, defense contractor DRA. The company and its supporting investors and collaborators will be required to match dollar for dollar any Third Frontier grant awarded, as per the requirements of the technology program.

Grid Sentry LLC develops and provides products and services to the power industry to monitor and manage the electric power distribution grid with emphasis on the segment between the sub-station and the user’s meter.

Grid Sentry’s sensor products are named “Line Sentry” (GS 200) and “PQ Sentry” (GS 300). These “Smart Grid Sensors” (SGS) are installed on power lines with a hot stick to help utilities identify inefficiencies which might cause them to use secondary generation sources to meet peak demand loads. The sensors employ power harvesting technology, and thus, require no batteries.

The sensors are designed to optimize load management of low power distribution lines in the range of 4-35kV. Using wireless technology which includes cellular, WiFi/WiMax, Zigbee, 2.5 Ghz, or BPL communications, the SGS monitor and transmit data on current load, fault current waveforms, power factor, conductor temperature to identify line sag, harmonics, and “Last Gasp” (line out) which provides data failure indication for low current or extended outage power loss. This real- time data enables utilities to improve load forecasting, detect and locate power outages, line imbalances and energy usage. Their security features enable the detection of terrorist attacks, natural disasters and power theft.

Prototypes of the products were put in use at Dayton Power & Light Company in late 2010, and the company proposed to start wide scale sales of its products to major US utilities in May of 2011.

Awesense Wireless

Awesense Wireless has been gaining a lot of attention in the utility industry. The Vancouver, BC based company was recently nominated as one of 2013 “Smart Grid Companies to Watch” by Smart Grid News. In addition, the company was named last month as an Emerging Rocket for the second year in a row as one of the top fourteen 2013 Cleantech Emerging companies in the Rocket Builders ranking of emerging British Columbia technology companies. The Emerging Rockets is a unique business recognition list that profiles technology companies with great potential for significant growth, investment and market breakthroughs in the coming year. And as early as 2011, Awesense won the $40,000 BC Hydro Sustainability Prize, and today the company is part of BC Hydro’s goal to reduce power theft by $100 million a year.

Founded in late 2009, the company has developed a breakthrough product that uses power line sensors connected through a wireless mesh network combined with a cloud-based application. Utility workers can use the combination to remotely monitor and learn details about how much power their companies are actually distributing, versus how much power is being measured by their billing systems. This information makes it clear to utilities how much revenue they are losing on a consistent basis due to theft or equipment failure.

The “awesome” part of the Awesense technology is the fact that it is can be operated in a mobile fashion. Utilities can move networked sensors from one section of the grid to another, testing each out, discovering its inefficiencies, fixing them, and then moving them on. Utilities are eyeing this technology world-wide because, in addition to the increase in revenue from recovered losses, utilizing movable sensors is a lot cheaper than installing a lot of permanent sensors on all portions of the grid, and at a fraction of the cost that would be required for a full-blown DA deployment. The economies of scale allow utilities to roll deployment costs into their grid operations and management budgets, thus averting the need to make a rate case for capital investments. Awesense recently offered another affordable solution for utilities that face challenges for investing in upfront gear. The company launched a service-based version of their business (“senseNET”) which will allow utilities to pay for deployments by means of a revenue-sharing agreement. Awesense already has one US utility with approximately 34,000 meters and 1,800 miles of lines using senseNET under just such a service contract, and is also working with utilities in Malaysia, Turkey, Bulgaria, and the Czech Republic.

Awesense “Raptors” are easy to deploy line monitors that wirelessly communicate to the “SenseNET” system, which is a comprehensive solution combining hardware, loss analysis, and networking and advanced power monitoring for identifying, characterizing and verifying power losses from equipment failures as well as power diversion. Its portable amperage monitors provide accurate data collection, secure wireless communications and the SenseNET suite of software applications which are available in cloud or client-hosted options. In addition, SenseNET monitors can create a commercial and industrial inspection paradigm to verify that the meter information on the most important customer groups has been tested. It can be used to catch incorrect multipliers, improper installations, burned or malfunctioning current transformers or phase transformers within minutes. The SenseNET monitors can be installed for days or a week to create detailed load profiles.

In December of 2012, Awesense secured private equity funding to accelerate their business growth. Although details of the funding haven’t been made public, industry experts believe the investment represents an amount in the 6-7 figures.

While Awesense has already helped North American customers like Fortis BC and others recover tens of millions of dollars in losses, it has also begun to collaborate with ELO Sistemas Eletronicos to bring the technology to Latin America. The Awesense Raptor, the company’s portable wireless power monitor, and Awesense senseNET revenue protection applications will now be promoted, marketed and sold by ELO in Latin America. The two companies are working closely together to integrate the Awesense senseNET system into ELO’s expanding suite of products and services. The system is ready for pilots throughout Latin America and volume rollouts were scheduled to be ready by the end of 2012.

Awesense first tested its system with utility Fortis BC, British Columbia’s biggest utility in 2011. The company is also working with unnamed AMI vendors to integrate its data into their systems. Awesense is an application partner for eMeter and also has international partners/strategic alliances. In addition to ELO in Brazil, they include Kazanc Energy in Turkey, Intellimeter and Clevest Solution, Inc. in Canada, and the US based giant, Cisco.

UtiliData, Inc.

UtiliData is a leading innovator of volt/VAR optimization solutions for the utility industry. Their “AdaptiVolt” system utilizes revolutionary digital signal processing (DSP) to control and optimize various devices on the distribution grid. This results in a low cost way to reduce power consumption and extend the life of equipment, as well as to deliver real-time data across a utility’s distribution system. The AdaptiVolt system is a subset of smart grid applications that are applied to the electric grid to improve efficiency. It extracts the underlying behavior of the electric distribution grid and uses that information to make near-optimal control decisions of power regulation devices. By reducing line losses and delivering optimal voltage levels to all customers, the system can reduce energy usage and peak demand by up to 5%. In addition, the system optimizes control operations, improving reliability and reducing maintenance costs.

DSP has the promise to fundamentally change the way the utility industry defines the grid. One of UtiliData’s biggest pilots with AEP in Ohio has showed results suggesting that the company’s DSP methods may outperform rival script and model-based systems. The company’s DSP methods allow it to capture more voltage savings, roughly 1-1.5% more than rule-or model-based systems, which results in up to 30-40% better performance. It also helps fix a problem other systems have with automated load tap changers which tend to activate more often when CVR equipment is in play. UtiliData’s system, on the other

hand, takes control to reduce tap changer use which should result in a longer life for those expensive pieces of equipment. That’s a key part of UtiliData’s differentiation from its rivals/partners in the market.

UtiliData isn’t the only smart grid vendor using DSP. Competitors like ABB and SEL use it for their substation protective relays and other large-scale automation projects. However, using DSP at the feeder-line scale that UtiliData is targeting is rarer. UtiliData may be a small player in the field of digitally controlling grid voltage, but if its AdaptiVolt system works as well as certain pilot projects seem to suggest, it could become a real contender against the heavy weights competing for the multi-billion dollar market.

A landmark event for UtiliData occurred in February 13, 2012 when the company completed a round of financing led by Braemar Energy Ventures. The undisclosed amount of funding came in the wake of the successful system performances and operational excellence demonstrations of AdaptiVolt in major utilities across North America. The financing will be used to build the company’s AdaptiVolt system into a product that’s scalable to large utility customers while aiming at cutting the per-feeder line costs of today’s systems in half. In addition to the financing, Scott DePasquale, Partner at Braemar Energy Ventures, joined the UtiliData board of directors as Chairman. He brings with him Braemar’s established portfolio and network in energy efficiency and grid technology, as well as their regulatory experience.

Just six days earlier, UtiliData announced the relocation of its operations from Spokane, Washington to Providence, RI, a regional nest of the technical talent required to further evolve UtiliData’s product offerings around power systems and advanced distribution automation. The State of Rhode Island’s Economic Development Corporation committed to financing the company’s working capital needs during this growth phase by providing $500,000 through its Renewable Energy Fund loan with the agreement that UtiliData will create a total of 47 full-time jobs in Rhode Island by the end of 2015.

In January of 2013, UtiliData announced a joint agreement with the multi-state utility AEP to advance the next generation of grid side applications that will be built on UtiliData’s innovative digital technology platform. AEP has been a longtime partner. It has deployed UtiliData’s AdaptiVolt technology on six circuits in Ohio and is in the process of adding it to nine more in Indiana. UtiliData has also worked with Silver Spring Networks on AEP pilots, as the company’s product interoperates with the SSN’s wireless mesh system, as well as via standard SCADA networks.

The research and development agreement between AEP and UtiliData will accelerate the application of digital control technologies to high value smart grid solutions. As part of the collaboration, technical and commercial leaders from AEP will support the product development work being done at UtiliData’s newly commissioned smart grid simulation and research center in Providence. The new UtiliData facility is designed to support the testing of current and future digital control technologies that will deliver superior volt/VAR optimization, peak demand reduction and conservation voltage reduction in an environment that can simulate real-world conditions on the electric grid. The collaborative approach will entail looking at new areas where DSP could improve utility operations, including fault indication, integration of distributed generation and electric vehicles on the distribution system.

IUS (Integrated Utility Solutions) Technologies

IUS is a subsidiary of the Vitzro Group, the $1 billion South Korean SCADA and grid control giant and one of South Korea's leading smart grid technology manufacturers. The company is entering the US market in a big-time way with plans to be the leader in providing distribution technology for utilities and working with companies like Siemens, GE, Cooper Systems, SAIC and AEP. The Vitzro Group has funded the creation of an entire self-standing US subsidiary and has purchased a 20,000 square foot multi-

million dollar plant located in Alpharetta, GA., where they anticipate hiring local engineers, technicians and staff to manufacture the IUS “Born Smart” sensor devices.

The distribution automation technology of the “Born Smart” sensors played a vital role in creating a stable South Korean electric system, thought to be one of the best in the world. The “VS” series of smart sensors (VS-1000 for single-phase applications and VS-3000 for three-phase applications) are ideal for end of line monitoring. They streamline the use of utility radio bandwidth, reducing communication loads up to 95%, and with up to 0.3% accuracy. The Born Smart Devices have the ability to react in a reflexive manner, utilize all available information to make decisions, learn from operating experiences, support rich communications with the surrounding distribution system and leverage existing and emerging standards.

The company, as well as some industry experts, claim that there are no other sensors on the market that provide such a level of accuracy with such a low cost of ownership, the latter of which will allow utilities to place sensors approximately every mile as necessary in order to create an extremely stable and reliable grid.

The decision to bring the product line and manufacturing facilities were largely driven by a successful pilot test conducted with AEP in late 2011 to assess the accuracy of IUS’s end-of-line smart sensors. Since AEP serves an 11 state area with more than five million customers, IUS had access to a wide market sample. The results confirmed the resiliency, up-time, and smart rerouting capabilities of IUS’s VS-1000 and VS-3000 sensors.

The sensors allow utilities to monitor and drop voltage levels across the grid, significantly increasing capacity, and allowing electric utilities to sell off the excess power to other utilities, municipalities or co-ops at the market rate. The net effect is creating a significant revenue stream for utilities and allowing capacity to meet the rising demand without costly infrastructure investments.

The VS-3000 is more accurate than the competition, at about 0.3 % precision on voltage measurements, compared to 0.7%-1%. This is partly because IUS uses a mathematically precise method which includes measurements of something called “true RMS voltage,” where RMS stands for root mean square. To do much of the math that goes into delivering this precision, the VS-3000 holds more processing power than the typical sensor, with a built-in microcontroller and 24-input, 8-output RTU that’s able to do more advanced logic to control things like capacitor banks and other nearby substations. IUS uses a networking feature called “unsolicited response,” meaning that the devices filter a lot of data themselves, picking and choosing what they send up the network to the master control system, thus saving on bandwidth and network constraints. Communication is achieved via DNP-3 and other SCADA grid protocols, as well as utility radio systems or cellular networks. The VS-3000 also has I/O communication capabilities so custom programming can be performed to fit specific needs.

IUS is working on the development of other applications for their sensors. The company is working on projects with grid operators in South Korea to prepare for peak power loads like those that Seoul experiences on summer afternoons. They have also been looking at demand response markets in California and Texas and have been working on strategic partnerships with SCADA and DMS vendors such as Siemens and SAIC on approaches that could help fine-tune DR.

At the 2014 DistribuTECH conference, IUS announced a new line of monitors that combine three measurements of distribution transformer health; temperature, power, and total combustible gas (TCG), all into a single unit. IUS’s new sensors monitor all three in real time.

PowerSense A/S 

PowerSense A/S was founded in 2006 as a spin-off from the Danish power company DONG Energy and the Danish venture capital fund NES Partners. The company develops and produces monitoring and control equipment with integrated supervision that has been designed to retrofit and digitalize existing power for utility distribution infrastructures. The company’s technology enables utilities to prepare their existing power infrastructures for tomorrow’s smart grid.

The company is in operation globally and active in four primary markets, those being Australia and New Zealand, China, Europe and North America. In addition, the company piggy-backs its products with a number of business partners in other geographical areas such as South America, the Middle East and parts of Asia.

The PowerSense system and product line is called “DISCOS”. As part of its offering, PowerSense offers a wide range of specially designed sensors. For MV power measurements, the company offers a patented sensor range based on optical technology. The company also offers a wide range of traditional LV sensor types, designed for fault detection, three-phase diagnostics, current flow, power quality measurements and analytics.

The DISCOS “Opti Module” is part of the system and is designed for the supervision of MV/LV cables and overhead lines with or without substations, as well as transformer bays. It constantly monitors power grid conditions using a wide range of threshold values while measuring currents from 5-20,000 AAC on cables and overhead lines. The module can operate on power installations with voltages up to 36kVAC and can also be used to control external switchgear. The “Outdoor Current Sensor” is part of the Opti module and monitors the current amplitude and the phase angle on both the LV and MV side of the transformer. The “Outdoor Combined Sensor” measures the current and voltage amplitude and the phase angle on the MV power grid.

The “SmartCom RTU” module is also part of the system. It is designed to link and integrate the DISCOS System into high-level IT systems like SCADA solutions or other grid management IT platforms. It is based on an “ARM” processor running Linux, which offers substantial flexibility in terms of supporting standard or customized protocols. In addition, the module has a wide range of interfaces to allow numerous communication possibilities, additional third-party hardware integration, and memory expansion.

The company’s “Smart Grid Device Integrator” can be combined with any of the products in the DISCOS family. If it is combined with the Optimodule, the solution can work as an MV supervision device of 3 MV phases (1 transformer bay) and voltage supervision of 3 LV phases. If it is combined with an I/O module, the solution can work as an LV supervision and power quality device of up to 12 LV phases (4 transformer bays) and voltage supervision of 3 LV phases. The current and voltage supervision methodologies of both solutions include current and voltage measurements, active and reactive power measurements and voltage and current alarms. PowerSense has strategic partnerships with IBM, BPL Global, and TDQS, the latter representing work in the Chinese market.

OptiSense

Founded in 2001, Texas-based OptiSense Network, LLC develops and manufactures optical MV and current sensors for automating electrical distribution networks to enable a Smart Grid from the substation-to-end user. Storing 15,000 measurements per second, the company’s “OptiSensors” employ a patented

crystal-optic technology to provide high-accuracy measurements of current, voltage and power factor on all three phases of distribution feeders, including high frequency components. The high average accuracy of the sensors (± 0.5%) vs. competitive sensors with accuracy of ± 5%) are of particular importance for the success of initiatives such as Demand Response, volt/VAR control and Conservation Voltage Optimization, enabling electric power companies to improve distribution system reliability, efficiency, and control in real-time.

OptiSense’s 15KV, 25KV, 35KV, and 46KV sensor solutions are used by distribution utilities and operators in North America, EMEA, Asia, and Latin America. With a life expectancy of twenty years or more, they make distribution routing decisions to remedy problems and shift power before a minor fault can become a major outage. They also increase the reliability of an aged and/or stressed infrastructure by better maintaining and managing line assets. The OptiSensors create a real-time state “map” of current and voltage on distribution lines and can locate energy theft at the neighborhood level by automatically detecting inconsistent voltage readings. They also have the ability to provide intelligence regarding bidirectional and multidirectional power generation such as wind power and solar.

Distribution planners are constantly challenged by new conditions affecting performance, such as capacity constraints, changing load profiles, distributed generation and renewables. To address these challenges, OptiSense provides two versions of the OptiSensors in a variety of voltage classes: The OptiSense voltage-only sensor accurately measures line to ground voltage, and the The OptiSense combo sensor accurately measures both line current, including direction of flow and line to ground voltage.

OptiSense also provides the “OptiSense Processor” (OSP), an electronics unit that translates the optical signals from the OptiSensors into either digital or analog outputs. The OptiSense Processor consists of optical processing boards, a common signal processing board, and an analog voltage output board. The optical processing boards precondition the optical signal applied to the OptiSensor and convert the optical signals received from the OptiSensor into a format suitable for analysis and processing by the digital processing board. The digital processing board has a digital signal processor (DSP) and a general purpose ARM processing core with the necessary supporting memory and peripherals. The DSP performs the complex mathematical operation needed to translate the optical inputs from the OptiSensors into accurate voltage, current and phase measurement values. Further processing is performed to calculate power quality and other power-related statistics. The general-purpose ARM provides the control interface and supports the DNP3 protocol stack. An Ethernet port provides the DNP3 communications interface and a serial port is provided for local configuration and monitoring.

An analog voltage output board provides voltage outputs that are proportionally related to the line voltages and currents. A maximum of six analog outputs are available to support the combination OptiSensors, providing support for 3-phases of both voltage and current.

The company promotes the cost efficiency of its OptiSensors on its web site. OptiSense claims the cost savings that can be achieved in network operations and maintenance is 20%, and that utilities may realize up to a 100% ROI in less than two years.

Lumasense

Lumasense provides temperature and gas sensing solutions for an array of applications. In the T&D area, they provide a solution to monitor sulfur hexafluoride (SF6) which is an insulating medium used in high-voltage switch gears and circuit breakers, as well as in cables, tubular transmission lines and transformers. In May of 2012, they also released an infrared gas analyzer (DGA) to additionally protect transformers.

On November 14, 2012, Lumasense released the results of a survey they conducted with worldwide power industry professionals. One of the survey findings confirmed that transformer DGA, winding hot spots and LTC DGA are considered the three most important elements to monitor on transformers, and the company provides instruments to measure all three elements, including a fiber optic portfolio acquired from Canada’s Opsens which enables utilities and transformer manufacturers to enhance reliability, including on distribution units.

LIOS Technology

LIOS Technology develops and supplies frequency domain-based distributed temperature monitoring systems (DTS) comprised of real-time fiber optic based linear temperature measuring devices. Among other critical applications, their DTS technology is utilized for power cable, aerial T&D line monitoring, and/or underground power lines.

As part of 2500 worldwide installations, current North American customers utilizing LIOS DTS of underground T&D cables are PEPCO (Washington, D.C.) and BC Hydro (Vancouver, Canada).

SensorTran

SensorTran, a NASA technology spin-off which became a wholly owned subsidiary of Halliburton in June of 2011, designs and supplies advanced fiber and optic distributed temperature sensing (DTS) systems utilizing a wide range of fiber optic sensing cables to monitor T&D power systems. DTS is recognized as a key Smart Grid technology as it allows users to access to real-time distributed temperature monitoring to maximize the current-carrying capacity within thermal limits, monitor circuit health, and optimize loading in actual estimates of ambient thermal conditions.

In addition to Halliburton, SensorTran customers include some of the world’s largest energy providers, including Houston-based Baker-Hughes.

On-Ramp Wireless

On-Ramp Wireless has developed a wireless system to connect hard-to-reach devices in metro-scale and other challenging environments. In metro-scale deployments, their “Ultra-Link Processing” (ULP) wireless communication system enables utilities to deploy one network for all of their distributed monitoring needs, whether it be AMI, fault circuit indicator, smart transformer monitoring or substation monitoring. On-Ramp’s solution can service both powered and battery-operated sensors in below-ground locations of the utility environment and across disparate geographies. The company has also introduced a certified Smart Grid and infrastructure monitoring and automatic alarm notification device. On-Ramp’s Remote Monitoring Unit (RMU) provides 24/7 monitoring and alarm notification messaging for solar-powered and line-powered obstruction warning lights in transmission towers, cell towers and other structures. The units can be used to “smart enable” any digital or analog sensor and include intrusion detection and battery backup for continued alarm notifications during outages.

On August 8, 2012, On-Ramp Wireless announced the results of its U.S. DOE funded field trials at San Diego Gas & Electric and Southern California Edison. The company’s project team members were awarded a $2.1 million project to integrate and demonstrate its wireless network solution for below-ground distribution automation, including outage detection and distribution transformer monitoring. The project performance exceeded the DOE’s 2016 Smart Grid Performance Target to improve the system

average interruption duration index (SAIDI), an important metric of electric grid reliability, by greater than 10%.

Alstom

Alstom provides Grid Instrument Transformers for AC or DC applications utilizing compact optical sensor intelligence (COSI) with direct digital output. All signals are transmitted through a standard fiber optic cable. Alstom’s Grid Current Transformer (COSI-NXCT) was developed by NxtPhase, a pioneer in optical current transformers. NxtPhase is now a part of Alstom Grid Instrument Transformers.

Alstom’s optical products are installed around the world in more than 300 substations in 19 countries. In March of 2010, to meet the specific requirements of China’s Smart Grid, COSI-NXCT underwent a dynamic simulation test on a 500 kV transformer substation protection relay in the China Electric Power Research Institute (CEPRI). More recently (October 2012), Alstom became engaged in a North Carolina Smart Grid project led by the DOE designed to integrate distributed energy resources into the electric grid in order to help the DOE reach its Smart Grid targets, including a 40% improvement in system efficiency. Alstom contributed its Integrated Distribution Management System (iDMS) which is capable of integrating multiple types of distributed resources and monitoring information from several distributed interfaces.

G&W Electric

A long time leader in the area of automated switchgears, G&W Electric’s expertise has now enabled them to move from being a component supplier to a complete automation system integrator. They provide a “Lazer Automation System” whose offerings cover the main automation requirements including automatic transfer, voltage loss reconfiguration, fault isolation reconfiguration, and the automatic restoration of faulted circuits that have lost voltage in 5kV and 38kV Smart Grid networks. On February 1, 2012, the company announced that they have added the capability of incorporating six integral voltage sensors to its “Viper-S” recloser line, a feature that was previously introduced on their “Viper-ST” models. The sensors permit voltage measurement on both the line and load sides of the recloser which is especially important to customers working on any type of distribution automation project including FDIR, automatic transfer, distributed generation and open bus-tie breakers.

On January 1, 2012, G&W Electric and Survalent Technology announced they are combining their respective experiences in providing automation solutions to develop a comprehensive solution offering users the ability to monitor, evaluate and reconfigure their systems while providing increased reliability, data analysis, reporting and improved efficiencies which can be used for SCADA management, FDIR, Smart Grid, load flow management and more.

Schneider Electric

With the acquisition of Areva’s T&D Distribution Division in June of 2010, Schneider Electric became one of the world leaders in medium-voltage and automation for electrical distribution. One of their five business groups, Infrastructure (previously called Energy) specializes in medium-voltage applications, especially for infrastructure and electrical utilities. They provide disconnectors, circuit breakers, transformers, medium-voltage cells and SCADA management systems, as well as software for the integrated management of mission critical infrastructure. For its industrial customers and OEMs,

Schneider Electric offers a wide range of industrial control products such as contactors, overload relays and motor circuit breakers, speed drive motion controllers, sensors, control units and operator terminals.

The customized sensors that were previously provided by the CST (Custom Sensor Technologies) business became part of the Industry Business at the start of 2011, bringing with it the biggest range of sensors on the market.

GRID20/20

GRID20/20 is a leading provider of comprehensive Distribution Transformer Monitoring solutions marketed as OptaNODE. The product family features patented high accuracy intra-grid sensors and the industry's fastest deployment capability. In addition to patented hardware, GRID20/20 provides proprietary software and analytics to maximize end user value. By employing wide-ranging device communications options and the ability to interface data with existing SCADA, MDM, and AMI collection engines, the OptaNODE solution is versatile and globally relevant.

GRID20/20 addresses a host of distribution optimization and automation needs, including critical asset loading data, preventive maintenance awareness, increased outage notification capability, costly power theft loss detection, conservation voltage enhancements, and many additional smart grid value propositions.

In addition, GRID20/20® OptaNODE DTM intra-grid sensors can be used to optimize the grid as distributed generation and electric vehicles become more prevalent.

Market Opportunities

Scalable and interoperable sensor solutions will best be positioned for market penetration as utilities will need to ensure sensors can integrate with future systems that can collect and process more data.

Sensors that can provide the most functionality at the best price will ultimately win over utilities. Further, utilities will continue to demand more uses and data to be provided from sensors.

California utilities PG&E, Southern California Edison, and San Diego Gas & Electric have the most aggressive plan to invest in transmission and distribution monitoring system technologies over the next 10 years. As part of Energy Strong, PSE&G’s $1 billion post-Sandy hardening plan, the utility plans to spend $100 million on FLISR. Even after getting whittled down by regulators from its original $3.9 billion spending target, it will be one of the biggest rounds of spending on distribution grid intelligence since Sandy.

PECO, Progress Energy, and Duke Energy are three additional utilities with plans for significant investments in transmission and distribution monitoring system technologies.

Distribution automation projects in the U.S. will fuel demand for distribution sensors over the next 10 years.

Near-term opportunities will be focused on voltage, current, and phase measurement units on the distribution network for fault detection, feeder line voltage optimization and capacitor bank control, as well as transformer monitoring.

Recommendations

Sensors that can provide the most functionality at the best price will ultimately win over utilities. Further, utilities will continue to demand more uses and data to be provided from distribution line sensors. Such demand will leave little room for low-end solutions among progressive utilities. That being said, developing countries will certainly deploy low-end sensors at a high rate given the budget constraints associated with utilities in the developing world.

Consider seizing market revenues from municipalities and cooperatives in the U.S. Although their expected spending is less than IOUs, these utilities see the value in deploying sensor technologies and are in later stages of their overall smart grid deployments. Their relatively small budgets have kept some of the major players away, thus creating an opening for QinetiQ.

Manufacturers that offer value added services and participate in pilot projects or with utilities to develop a business case for their sensors will be best poised to take advantage of the market.