US20210181774A1 - Voltage conservation using advanced metering infrastructure and substation centralized voltage control - Google Patents

Abstract

A voltage control and conservation (VCC) system is provided, which includes three subsystems, including an energy delivery (ED) system, an energy control (EC) system and an energy regulation (ER) system. The VCC system is configured to monitor energy usage at the ED system and determine one or more energy delivery parameters at the EC system. The EC system may then provide the one or more energy delivery parameters to the ER system to adjust the energy delivered to a plurality of users for maximum energy conservation.

Description

CROSS-REFERENCE TO RELATED APPLICATIONS
• This application is a continuation application of application Ser. No. 13/931,145, filed Jun. 28, 2013, which is a continuation of application Ser. No. 12/774,507, filed May 5, 2010, now U.S. Pat. No. 8,577,520, issued Nov. 5, 2013, which claims priority and the benefit thereof from U.S. Provisional Application No. 61/176,398, filed on May 7, 2009 and entitled VOLTAGE CONSERVATION USING ADVANCED METERING INFRASTRUCTURE AND SUBSTATION CENTRALIZED VOLTAGE CONTROL, the entirety of which are herein incorporated by reference. This application is indirectly related to U.S. application Ser. No. 13/567,473, filed Aug. 6, 2012. now U.S. Pat. No. 8,437,883, issued May 7, 2013, and U.S. application Ser. No. 14/554,917, filed Nov. 26, 2014.
FIELD OF THE DISCLOSURE
• The present disclosure relates to a method, an apparatus, a system and a computer program for conserving energy. More particularly, the disclosure relates to a novel implementation of voltage conservation using advanced infrastructure and substation centralized voltage control.
BACKGROUND OF THE INVENTION
• Electricity is commonly generated at a power station by electromechanical generators, which are typically driven by heat engines fueled by chemical combustion or nuclear fission, or driven by kinetic energy flowing from water or wind. The electricity is generally supplied to end users through transmission grids as an alternating current signal. The transmission grids may include a network of power stations, transmission circuits, substations, and the like.
• The generated electricity is typically stepped-up in voltage using, for example, generating step-up transformers, before supplying the electricity to a transmission system. Stepping up the voltage improves transmission efficiency by reducing the electrical current flowing in the transmission system conductors, while keeping the power transmitted nearly equal to the power input. The stepped-up voltage electricity is then transmitted through the transmission system to a distribution system, which distributes the electricity to end users. The distribution system may include a network that carries electricity from the transmission system and delivering it to end users. Typically, the network may include medium-voltage (for example, less than 69 kV) power lines, electrical substations, transformers, low-voltage (for example, less than 1 kV) distribution wiring, electric meters, and the like.
• The following describe subject matter related to power generation or distribution: Power Distribution Planning Reference Book, Second Edition, H. Lee Willis, 2004; Estimating Methodology for a Large Regional Application of Conservation Voltage Reduction, J. G. De Steese, S. B. Merrick, B. W. Kennedy, IEEE Transactions on Power. Systems, 1990; Implementation of Conservation Voltage Reduction at Commonwealth Edison, IEEE Transactions on Power Systems, D. Kirshner, 1990; and Conservation Voltage Reduction at Northeast Utilities, D. M. Lauria, IEEE, 1987. Further, U.S. Pat. No. 5,466,973, issued to Griffioen on Nov. 14, 1995, describes a method for regulating the voltage at which electric energy is supplied at the delivery points in a network for distributing electricity.
• The disclosure provides a novel method, apparatus, system and computer program for conserving energy in electric systems. More particularly, the disclosure provides a novel solution to conserve energy by implementing voltage conservation using advanced infrastructure and substation centralized voltage control.
SUMMARY OF THE DISCLOSURE
• According to an aspect of the disclosure, a voltage control and conservation (VCC) system is provided for monitoring, controlling and conserving enemy. The VCC system comprises: a substation configured to supply electrical power to a plurality of user locations; a smart meter located at one of the plurality of user locations and configured to generate smart meter data based on a measured component of electrical power received by the smart meter; and a voltage controller configured to generate an energy delivery parameter based on the smart meter data, wherein the substation is further configured to adjust a voltage set point value of the electrical power supplied to the plurality of user locations based on the energy delivery parameter, and wherein the smart meter is configured to operate in a report-by-exception mode and sua sponte send the smart meter data to the voltage controller when the measured component of electrical power is determined to be outside of a target component band.
• The VCC system may further comprise a second smart meter located at a second one of the plurality of user locations and configured to generate second smart meter data based on a second measured component of electrical power received by the second smart meter, wherein the voltage controller is further configured to determine an average user voltage component by averaging the measured component of electrical power received by the smart meter and the second measured component of electrical power received by the second smart meter.
• The VCC system may further comprise a collector configured to receive the smart meter data from the smart meter and generate collector data, wherein the voltage controller is further configured to generate the energy delivery parameter based on the collector data.
• In the VCC system, the target component band may include a target voltage band, and the voltage controller may be configured to compare the measured component of electrical power received by the smart meter to the target voltage band and adjust the voltage set point based on a result of the comparison.
• The substation may comprise: a load tap change transformer that adjusts the voltage set point value based on a load tap change coefficient; or a voltage regulator that adjusts the voltage set point value based on the energy delivery parameter. The substation may comprise a distribution bus that supplies the electrical power to the plurality of user locations, wherein an electrical power supply voltage component is measured on the distribution bus.
• The voltage controller may comprise: a meter automation system server (MAS); a distribution management system (DMS); and a regional operation center (ROC). The voltage controller may be configured to adjust the voltage set point at a maximum rate of one load tap change step. The voltage controller may be configured to adjust the voltage set point based on the average user voltage component. The voltage controller may be configured to maintain the measured component of electrical power received by the smart meter within the target voltage band based on the result of the comparison. The voltage controller may be configured to select said smart meter for monitoring and create a connection to said smart meter after receiving the smart meter data sent sua sponte by said smart meter while operating in the report-by-exception mode. The voltage controller may be configured to de-select another smart meter that was previously selected to be monitored. The voltage controller may be configured to create a connection to said smart meter and terminate a connection to said another smart meter. The sua sponte smart meter data received from said smart meter may be representative of a low voltage limiting level in the system. The voltage controller may be configured to: store historical component data that includes at least one of an aggregated energy component data at a substation level, a voltage component data at a substation level, and a weather data; determine energy usage at each of the plurality of user locations; compare the historical component data to the determined energy usage; and determine energy savings attributable to the system based on the results of the comparison of the historical component data to the determined energy usage. The voltage controller may be configured to determine energy savings attributable to the system based on a linear regression that removes effects of weather, load growth, or economic effects. The voltage controller may be further configured to increase the voltage set point when either the electrical power supply voltage component or the average user voltage component falls below a target voltage band.
• According to a further aspect of the disclosure, a VCC system is provided that comprises: a substation configured to supply electrical power to a plurality of user locations; a smart meter located at one of the plurality of user locations and configured to generate smart meter data based on a measured component of electrical power received by the smart meter; and a voltage controller configured to control a voltage set point of the electrical power supplied by the substation based on the smart meter data. The smart meter may be configured to operate in a report-by-exception mode, which comprises sua sponte sending the smart meter data to the voltage controller when the measured component of electrical power is determined to be outside of a target component band.
• The VCC system may further comprise: a second smart meter located at a second one of the plurality of user locations, the second smart meter being configured to generate second smart meter data based on a second measured component of electrical power received by the second smart meter, wherein the voltage controller is further configured to determine an average user voltage component by averaging the measured component of electrical power received by the smart meter and the second measured component of electrical power received by the second smart meter.
• The substation may comprise: a load tap change transformer that adjusts the voltage set point value based on a load tap change coefficient; or a voltage regulator that adjusts the voltage set point value based on the energy delivery parameter. The substation may comprise a distribution bus that supplies the electrical power to the plurality of user locations, wherein an electrical power supply voltage component is measured on the distribution bus.
• The voltage controller may be configured to increase the voltage set point when either the electrical power supply voltage component or the average user voltage component falls below a target voltage band. The voltage controller may be configured to adjust the voltage set point at a maximum rate of one load tap change step. The voltage controller may be configured to compare the measured component of electrical power received by the smart meter to a target component band and adjust the voltage set point based on a result of the comparison. The voltage controller may be configured to adjust the voltage set point based on the average user voltage component. The target component band may include a target voltage band, and the voltage controller may be configured to maintain the measured component of electrical power received by the smart meter within the target voltage band based on the result of the comparison.
• According to a still further aspect of the disclosure, a method is provided for controlling electrical power supplied to a plurality of user locations. The method comprises: receiving smart meter data from a first one of the plurality of user locations; and adjusting a voltage set point at a substation based on the smart meter data, wherein the smart meter data is sua sponte generated at the first one of the plurality of user locations when a measured component of electrical power that is supplied to the first one of the plurality of user locations is determined to be outside of a target component band.
• The method may further comprise maintaining the average user voltage component within the target voltage band. The method may further comprise measuring a voltage component of the supplied electrical power on a distribution bus. The method may further comprise increasing the voltage set point when either the electrical power supply voltage component or an average user voltage component falls below the target component band. The method may further comprise: selecting said smart meter for monitoring; and creating a connection to said smart meter after receiving the smart meter data sent sua sponte by said smart meter while operating in a report-by-exception mode. The method may further comprise de-selecting another smart meter from a group of smart meters previously selected to be monitored. The method may further comprise terminating a connection to said another smart meter. The method may further comprise: storing historical component data that includes at least one of an aggregated energy component data at a substation level, a voltage component data at a substation level, and a weather data; determining energy usage at each of the plurality of user locations; comparing the historical component data to the determined energy usage; and determining energy savings attributable to the system based on the results of the comparison of the historical component data to the determined energy usage. The target component band may include a target voltage band. The method may further comprise: determining the target voltage band; and comparing an average user voltage component to the target voltage band.
• The voltage set point may be adjusted based on the result of comparing the average user voltage component to the target voltage band. The sua sponte smart meter data received from the smart meter may be representative of a low voltage limiting level in the system.
• According to a still further aspect of the disclosure, a computer readable medium is provided that tangibly embodies and includes a computer program for controlling electrical power supplied to a plurality of user locations. The computer program comprises a plurality of code sections, including: a receiving smart meter data code section that, when executed on a computer, causes receiving smart meter data from a first one of the plurality of user locations; and a voltage set point adjusting code section that, when executed on a computer, causes adjusting a voltage set point at a substation based on the smart meter data, wherein the smart meter data is sua sponte generated at the first one of the plurality of user locations when a measured component of electrical power that is supplied to the first one of the plurality of user locations is determined to be outside of a target component band.
• The computer program may comprise an average user voltage component maintaining code section that, when executed on the computer, causes maintaining the average user voltage component within the target voltage band. The computer program may comprise a voltage component measuring code section that, when executed on the computer, causes a voltage component of the supplied electrical power to be measured on a distribution bus. The computer program may include a voltage set point increasing code section that, when executed on the computer, causes increasing the voltage set point when either the electrical power supply voltage component or an average user voltage component falls below the target component band. The computer program may comprise: a smart meter selection code section that, when executed on the computer, causes selecting said smart meter for monitoring; and a connection creation code section that, when executed on the computer, causes creating a connection to said smart meter after receiving the smart meter data sent sua sponte by said smart meter while operating in a report-by-exception mode. The computer program may comprise a smart meter de-selecting code section that, when executed on the computer, causes de-selecting another smart meter from a group of smart meters previously selected to be monitored. The computer program may comprise connection terminating code section that, when executed on the computer, causes terminating a connection to said another smart meter.
• The computer program may comprise: a storing code section that, when executed on the computer, causes storing historical component data that includes at least one of an aggregated enemy component data at a substation level, a voltage component data at a substation level, and a weather data; an energy usage determining code section that, when executed on the computer, causes determining energy usage at each of the plurality of user locations; a comparing code section that, when executed on the computer, causes comparing the historical component data to the determined energy usage; and an energy savings determination code section that, when executed on the computer, causes determining energy savings attributable to the system based on the results of the comparison of the historical component data to the determined energy usage. The target component band may include a target voltage band. The computer program may comprise: a target voltage band determining code section that, when executed on the computer, causes determining the target voltage band; and a comparing code section that, when executed on the computer, causes comparing an average user voltage component to the target voltage band. The voltage set point may be adjusted based on the result of comparing the average user voltage component to the target voltage band. The sua sponte smart meter data received from the smart meter may be representative of a low voltage limiting level in the system.
• Additional features, advantages, and embodiments of the disclosure may be set forth or apparent from consideration of the detailed description and drawings. Moreover, it is to be understood that both the foregoing summary of the disclosure and the following detailed description are exemplary and intended to provide further explanation without limiting the scope of the disclosure as claimed.
BRIEF DESCRIPTION OF THE DRAWINGS
• The accompanying drawings, which are included to provide a further understanding of the disclosure, are incorporated in and constitute a part of this specification, illustrate embodiments of the disclosure and together with the detailed description serve to explain the principles of the disclosure. No attempt is made to show structural details of the disclosure in more detail than may be necessary for a fundamental understanding of the disclosure and the various ways in which it may be practiced. In the drawings:
• FIG. 1 shows an example of an electricity generation and distribution system, according to principles of the disclosure;
• FIG. 2 shows an example of a voltage control and conservation (VCC) system, according to the principles of the disclosure;
• FIG. 3 shows an example of a control screen that may be displayed on a regional operation center (ROC) computer, according to principles of the disclosure;
• FIG. 4 shows an example of a voltage control and conservation (VCC) process according to principles of the disclosure;
• FIG. 5A shows an example of a process for monitoring the voltage component and electrical energy received and measured at selected smart meters, according to principles of the disclosure;
• FIG. 5B shows an example of a process for selecting a smart meter operating in a report-by-exception mode and de-selecting a previously selected smart meter, according to principles of the disclosure;
• FIG. 6 shows an example of a graph of a voltage of electric power supplied to users versus a time of day, according to principles of the disclosure;
• FIG. 7 shows an example of a graph of substation voltages of electric power produced by, for example, an LTC transformer at a substation, which may be associated with, for example, the information displayed on the control screen shown inFIG. 3;
• FIG. 8 shows an example of data collected (including voltage and energy measurement) hourly by the DMS in the example ofFIG. 7, before application of the voltage control according to the principles of the disclosure;
• FIG. 9 shows an example of the data collected (including voltage and energy measurement) hourly by the DMS in the example ofFIG. 7, after application of the voltage control according to the principles of the disclosure;
• FIG. 10 shows an example of calculation data for hours 1-5 and the average for the full twenty-four hours in the example ofFIGS. 7-9;
• FIG. 11 shows an example where data may be collected for weather variables for the days before and after voltage control and/or conservation, according to principles of the disclosure;
• FIG. 12 shows an example of an application of a paired test analysis process, according to principles of the disclosure;
• FIG. 13 shows an example of a scatterplot of kW-per-customer days with VCC ON to kW-per-customer days with VCC OFF;
• FIG. 14 shows an example of a summary chart for the data shown inFIG. 13, according to principles of the disclosure;
• FIG. 15 shows an alternative example of a scatterplot of historical data before the VCC system is implemented, according to principles of the disclosure;
• FIG. 16 shows an alternative example of a scatterplot of historical data after the VCC system is implemented, according to principles of the disclosure; and
• FIG. 17 shows an alternative example of a summary chart, including 98% confidence intervals, according to principles of the disclosure.
• The present disclosure is further described in the detailed description that follows.
DETAILED DESCRIPTION OF THE INVENTION
• The disclosure and the various features and advantageous details thereof are explained more fully with reference to the non-limiting embodiments and examples that are described and/or illustrated in the accompanying drawings and detailed in the following description. It should be noted that the features illustrated in the drawings are not necessarily drawn to scale, and features of one embodiment may be employed with other embodiments as the skilled artisan would recognize, even if not explicitly stated herein. Descriptions of well-known components and processing techniques may be omitted so as to not unnecessarily obscure the embodiments of the disclosure. The examples used herein are intended merely to facilitate an understanding of ways in which the disclosure may be practiced and to further enable those of skill in the art to practice the embodiments of the disclosure. Accordingly, the examples and embodiments herein should not be construed as limiting the scope of the disclosure. Moreover, it is noted that like reference numerals represent similar parts throughout the several views of the drawings.
• A “computer”, as used in this disclosure, means any machine, device, circuit, component, or module, or any system of machines, devices, circuits, components, modules, or the like, which are capable of manipulating data according to one or more instructions, such as, for example, without limitation, a processor, a microprocessor, a central processing unit, a general purpose computer, a super computer, a personal computer, a laptop computer, a palmtop computer, a notebook computer, a desktop computer, a workstation computer, a server, or the like, or an array of processors, microprocessors, central processing units, general purpose computers, super computers, personal computers, laptop computers, palmtop computers, notebook computers, desktop computers, workstation computers, servers, or the like.
• A “server”, as used in this disclosure, means any combination of software and/or hardware, including at least one application and/or at least one computer to perform services for connected clients as part of a client-server architecture. The at least one server application may include, but is not limited to, for example, an application program that can accept connections to service requests from clients by sending back responses to the clients. The server may be configured to run the at least one application, often under heavy workloads, unattended, for extended periods of time with minimal human direction. The server may include a plurality of computers configured, with the at least one application being divided among the computers depending upon the workload. For example, under light loading, the at least one application can run on a single computer. However, under heavy loading, multiple computers may be required to run the at least one application. The server, or any if its computers, may also be used as a workstation.
• A “database”, as used in this disclosure, means any combination of software and/or hardware, including at least one application and/or at least one computer. The database may include a structured collection of records or data organized according to a database model, such as, for example, but not limited to at least one of a relational model, a hierarchical model, a network model or the like. The database may include a database management system application (DBMS) as is known in the art. The at least one application may include, but is not limited to, for example, an application program that can accept connections to service requests from clients by sending back responses to the clients. The database may be configured to run the at least one application, often under heavy workloads, unattended, for extended periods of time with minimal human direction.
• A “communication link”, as used in this disclosure, means a wired and/or wireless medium that conveys data or information between at least two points. The wired or wireless medium may include, for example, a metallic conductor link, a radio frequency (RF) communication link, an Infrared (IR) communication link, an optical communication link, or the like, without limitation. The RF communication link may include, for example, WiFi, IEEE 802.11, DECT, 0G, 1G, 2G, 3G or 4G cellular standards, Bluetooth, and the like.
• The terms “including”, “comprising” and variations thereof, as used in this disclosure, mean “including, but not limited to”, unless expressly specified otherwise.
• The terms “a”, “an”, and “the”, as used in this disclosure, means “one or more”, unless expressly specified otherwise.
• Devices that are in communication with each other need not be in continuous communication with each other, unless expressly specified otherwise. In addition, devices that are in communication with each other may communicate directly or indirectly through one or more intermediaries.
• Although process steps, method steps, algorithms, or the like, may be described in a sequential order, such processes, methods and algorithms may be configured to work in alternate orders. In other words, any sequence or order of steps that may be described does not necessarily indicate a requirement that the steps be performed in that order. The steps of the processes, methods or algorithms described herein may be performed in any order practical. Further, some steps may be performed simultaneously.
• When a single device or article is described herein, it will be readily apparent that more than one device or article may be used in place of a single device or article. Similarly, where more than one device or article is described herein, it will be readily apparent that a single device or article may be used in place of the more than one device or article. The functionality or the features of a device may be alternatively embodied by one or more other devices which are not explicitly described as having such functionality or features.
• A “computer-readable medium”, as used in this disclosure, means any medium that participates in providing data (for example, instructions) which may be read by a computer. Such a medium may take many forms, including non-volatile media, volatile media, and transmission media. Non-volatile media may include, for example, optical or magnetic disks and other persistent memory. Volatile media may include dynamic random access memory (DRAM). Transmission media may include coaxial cables, copper wire and fiber optics, including the wires that comprise a system bus coupled to the processor. Transmission media may include or convey acoustic waves, light waves and electromagnetic emissions, such as those generated during radio frequency (RF) and infrared (IR) data communications. Common forms of computer-readable media include, for example, a floppy disk, a flexible disk, hard disk, magnetic tape, any other magnetic medium, a CD-ROM, DVD, any other optical medium, punch cards, paper tape, any other physical medium with patterns of holes, a RAM, a PROM, an EPROM, a FLASH-EEPROM, any other memory chip or cartridge, a carrier wave as described hereinafter, or any other medium from which a computer can read.
• Various forms of computer readable media may be involved in carrying sequences of instructions to a computer. For example, sequences of instruction (i) may be delivered from a RAM to a processor, (ii) may be carried over a wireless transmission medium, and/or (iii) may be formatted according to numerous formats, standards or protocols, including, for example, WiFi, WiMAX, IEEE 802.11, DECT, 0G, 1G, 2G, 3G or 4G cellular standards, Bluetooth, or the like.
• According to one non-limiting example of the disclosure, a voltage control and conservation (VCC)system200 is provided (shown inFIG. 2), which includes three subsystems, including an energy delivery (ED)system300, an energy control (EC)system400 and an energy regulation (ER)system500. TheVCC system200 is configured to monitor energy usage at theED system300 and determine one or more energy delivery parameters C_EDat the EC system (or voltage controller)400. TheEC system400 may then provide the one or more energy delivery parameters C_EDto theER system500 to adjust the energy delivered to a plurality of users for maximum energy conservation.
• TheVCC system200 may be integrated into, for example, an existing load curtailment plan of an electrical power supply system. The electrical power supply system may include an emergency voltage reduction plan, which may be activated when one or more predetermined events are triggered. The predetermined events may include, for example, an emergency, a short circuit, an overheating of electrical conductors, when the electrical power output from the transformer exceeds, for example, 80% of its power rating, or the like. TheVCC system200 is configured to yield to the load curtailment plan when the one or more predetermined events are triggered, allowing the load curtailment plan to be executed to reduce the voltage of the electrical power supplied to the plurality of users.
• FIG. 1 shows an example of an electricity generation anddistribution system100, according to principles of the disclosure. The electricity generation anddistribution system100 includes an electricalpower generating station110, a generating step-uptransformer120, asubstation130, a plurality of step-downtransformers140,165,167, andusers150,160. The electricalpower generating station110 generates electrical power that is supplied to the step-uptransformer120. The step-up transformer steps-up the voltage of the electrical power and supplies the stepped-up electrical power to anelectrical transmission media125.
• As seen inFIG. 1, the electrical transmission media may include wire conductors, which may be carried above ground by, for example,utility poles127 and/or underground by, for example, shielded conductors (not shown). The electrical power is supplied from the step-uptransformer120 to thesubstation130 as electrical power E_In(t), where the electrical power E_Inin Megawatts (MW) may vary as a function of time t. Thesubstation130 converts the received electrical power E_In(t) to E_Supply(t) and supplies the converted electrical power E_Supply(t) to the plurality ofusers150,160. Thesubstation130 may adjustably transform the voltage component V_In(t) of the received electrical power E_In(t) by, for example, stepping-down the voltage before supplying the electrical power E_Supply(t) to theusers150,160. The electrical power E_Supply(t) supplied from thesubstation130 may be received by the step-downtransformers140,165,167 and supplied to theusers150,160 through atransmission medium142,162, such as, for example, but not limited to, underground electrical conductors (and/or above ground electrical conductors).
• Each of theusers150,160 may include an Advanced Meter Infrastructure (AMI)155,169. TheAMI155,169 may be coupled to a Regional Operations Center (ROC)180. TheROC180 may be coupled to theAMI155,169, by means of a plurality ofcommunication links175,184,188, anetwork170 and/or awireless communication system190. Thewireless communication system190 may include, but is not limited to, for example, an RF transceiver, a satellite transceiver, and/or the like.
• Thenetwork170 may include, for example, at least one of the Internet, a local area network (LAN), a wide area network (WAN), a metropolitan area network (MAN), a personal area network (PAN), a campus area network, a corporate area network, a global area network (GAN), a broadband area network (BAN), or the like, any of which may be configured to communicate data via a wireless and/or a wired communication medium. Thenetwork170 may be configured to include a network topology such as, for example, a ring, a mesh, a line, a tree, a star, a bus, a full connection, or the like.
• TheAMI155,169 may include any one or more of the following: A smart meter; a network interface (for example, a WAN interface, or the like); firmware; software; hardware; and the like. The smart meter may be configured to determine any one or more of the following: kilo-Watt-hours (kWh) delivered; kWh received; kWh delivered plus kWh received; kWh delivered minus kWh received; interval data; demand data; and the like. If the smart meter is a three phase meter, then the low phase voltage may be used in the average calculation. If the meter is a single phase meter, then the single voltage component will be averaged.
• TheAMI155,169 may further include one or more collectors (shown inFIG. 2) configured to collect smart meter data from one or more smart meters tasked with, for example, measuring and reporting electric power delivery and consumption at one or more of theusers150,160. Alternatively (or additionally), the one or more collectors may be located external to theusers150,160, such as, for example, in a housing holding the step-downtransformers140,165,167. Each of the collectors may be configured to communicate with theROC180.
VCC System200
• FIG. 2 shows an example of theVCC system200, according to principles of the disclosure. TheVCC system200 includes theED system300, theEC system400 and theER system500, each of which is shown as a broken-line ellipse. TheVCC system200 is configured to monitor energy usage at theED system300. TheED system300 monitors energy usage at one ormore users150,160 (shown inFIG. 1) and sends energy usage information to theEC system400. TheEC system400 processes the energy usage information and generates one or more energy delivery parameters C_ED, which it sends to theER system500. TheER system500 receives the one or more energy delivery parameters C_EDand adjusts the electrical power E_Supply(t) supplied to theusers150,160 based on the received energy delivery parameters C_ED.
• TheVCC system200 minimizes power system losses, reduces user energy consumption and provides precise user voltage control. TheVCC system200 may include a closed loop process control application that uses user voltage data provided by theED system300 to control, for example, a voltage set point V_SPon a distribution circuit (not shown) within theER system500. That is, theVCC system200 may control the voltages V_Supply(t) of the electrical power E_Supply(t) supplied to theusers150,160, by adjusting the voltage set point V_SPof the distribution circuit in theER system500, which may include, for example, one or more load tap changing (LTC) transformers, one or more voltage regulators, or other voltage controlling equipment to maintain a tighter band of operation of the voltages V_Delivered(t) of the electric power E_Delivered(t) delivered to theusers150,160, to lower power losses and facilitate efficient use of electrical power E_Delivered(t) at theuser locations150 or160.
• TheVCC system200 controls or adjusts the voltage V_Supply(t) of the electrical power E_Supply(t) supplied from theEC system500 based on smart meter data, which includes measured voltage V_Meter(t) data from theusers150,160 in theED system300. TheVCC system200 may adjust the voltage set point V_SPat the substation or line regulator level in theER system500 by, for example, adjusting the LTC transformer (not shown), circuit regulators (not shown), or the like, to maintain the user voltages V_Meter(t) in a target voltage band V_Band-n, which may include a safe nominal operating range.
• TheVCC system200 is configured to maintain the electrical power E_Delivered(t) delivered to theusers150,160 within one or more voltage bands V_Band-n. For example, the energy may be delivered in two or more voltage bands V_Band-nsubstantially simultaneously, where the two or more voltage bands may be substantially the same or different. The value V_Band-nmay be determined by the following expression [1]:
• 
  V_Band-n=V_SP+ΔV  [1]
• where V_Band-nis a range of voltages, n is a positive integer greater than zero corresponding to the number of voltage bands V_Bandthat may be handled at substantially the same time, V_SPis the voltage set point value and ΔV is a voltage deviation range.
• For example, theVCC system200 may maintain the electrical power E_Delivered(t) delivered to theusers150,160 within a band V_Band-1equal to, for example, 111V to 129V for rural applications, where V_SPis set to 120V and ΔV is set to a deviation of seven-and-one-half percent (+/−7.5%). Similarly, theVCC system200 may maintain the electrical power E_Delivered(t) delivered to theusers150,160 within a band V_Band-2equal to, for example, 114V to 126V for urban applications, where V_SPset to 120V and ΔV is set to a deviation of five (+/−5%).
• TheVCC system200 may maintain the electrical power E_Delivered(t) delivered to theusers150,160 at any voltage band V_Band-nusable by theusers150,160, by determining appropriate values for V_SPand ΔV. In this regard, the values V_SPand ΔV may be determined by theEC system400 based on the energy usage information forusers150,160, received from theED system300.
• TheEC system400 may send the V_SPand ΔV values to theER system500 as energy delivery parameters C_ED, which may also include the value V_Band-n. TheER system500 may then control and maintain the voltage V_Delivered(t) of the electrical power E_Delivered(t) delivered to theusers150,160, within the voltage band V_Band-n. The energy delivery parameters C_EDmay further include, for example, load-tap-changer (LTC) control commands.
• TheVCC system200 may further measure and validate energy savings by comparing energy usage by theusers150,160 before a change in the voltage set point value V_SP(or voltage band V_Band-n) to the energy usage by theusers150,160 after a change in the voltage set point value V_SP(or voltage band V_BAND-n), according to principles of the disclosure. These measurements and validations may be used to determine the effect in overall energy savings by, for example, lowering the voltage V_Delivered(t) of the electrical power E_Delivered(t) delivered to theusers150,160, and to determine optimal delivery voltage bands for the energy power E_Delivered(t) delivered to theusers150,160.
ER System500
• TheER system500 may communicate with theED system300 and/orEC system400 by means of thenetwork170. TheER system500 is coupled to thenetwork170 and theEC system400 by means ofcommunication links510 and430, respectively. TheEC system500 is also coupled to theED system300 by means of thepower lines340, which may include communication links.
• TheER system500 includes asubstation530 which receives the electrical power supply E_In(t) from, for example, the power generating station110 (shown inFIG. 1) on aline520. The electrical power E_In(t) includes a voltage V_In(t) component and a current I_In(t) component. Thesubstation530 adjustably transforms the received electrical power E_In(t) to, for example, reduce (or step-down) the voltage component V_In(t) of the electrical power E_In(t) to a voltage value V_Supply(t) of the electrical power E_Supply(t) supplied to the plurality ofsmart meters330 on thepower supply lines340.
• Thesubstation530 may include a transformer (not shown), such as, for example, a load tap change (LTC) transformer. In this regard, thesubstation530 may further include an automatic tap changer mechanism (not shown), which is configured to automatically change the taps on the LTC transformer. The tap changer mechanism may change the taps on the LTC transformer either on-load (on-load tap changer, or OLTC) or off-load, or both. The tap changer mechanism may be motor driven and computer controlled. Thesubstation530 may also include a buck/boost transformer to adjust and maximize the power factor of the electrical power E_Delivered(t) supplied to the users onpower supply lines340.
• Additionally (or alternatively), thesubstation530 may include one or more voltage regulators, or other voltage controlling equipment, as known by those having ordinary skill in the art, that may be controlled to maintain the output the voltage component V_Supply(t) of the electrical power E_Supply(t) at a predetermined voltage value or within a predetermined range of voltage values.
• Thesubstation530 receives the energy delivery parameters C_EDfrom theEC system400 on thecommunication link430. The energy delivery parameters C_EDmay include, for example, load tap coefficients when an LTC transformer is used to step-down the input voltage component V_In(t) of the electrical power E_In(t) to the voltage component V_Supply(t) of the electrical power E_Supply(t) supplied to theED system300. In this regard, the load tap coefficients may be used by theER system500 to keep the voltage component V_Supply(t) on the low-voltage side of the LTC transformer at a predetermined voltage value or within a predetermined range of voltage values.
• The LTC transformer may include, for example, seventeen or more steps (thirty-five or more available positions), each of which may be selected based on the received load tap coefficients. Each change in step may adjust the voltage component V_Supply(t) on the low voltage side of the LTC transformer by as little as, for example, about five-thousandths (0.5%), or less.
• Alternatively, the LTC transformer may include fewer than seventeen steps. Similarly, each change in step of the LTC transformer may adjust the voltage component V_Supply(t) on the low voltage side of the LTC transformer by more than, for example, about five-thousandths (0.5%).
• The voltage component V_Supply(t) may be measured and monitored on the low voltage side of the LTC transformer by, for example, sampling or continuously measuring the voltage component V_Supply(t) of the stepped-down electrical power E_Supply(t) and storing the measured voltage component V_Supply(t) values as a function of time t in a storage (not shown), such as, for example, a computer readable medium. The voltage component V_Supply(t) may be monitored on, for example, a substation distribution bus, or the like. Further, the voltage component V_Supply(t) may be measured at any point where measurements could be made for the transmission or distribution systems in theER system500.
• Similarly, the voltage component V_In(t) of the electrical power E_In(t) input to the high voltage side of the LTC transformer may be measured and monitored. Further, the current component I_Supply(t) of the stepped-down electrical power E_Supply(t) and the current component I_In(t) of the electrical power E_In(t) may also be measured and monitored. In this regard, a phase difference φ_In(t) between the voltage V_In(t) and current140 components of the electrical power E_In(t) may be determined and monitored. Similarly, a phase difference φ_Supply(t) between the voltage V_Supply(t) and current I_Supply(t) components of the electrical energy supply E_Supply(t) may be determined and monitored.
• TheER system500 may provide electrical energy supply status information to theEC system400 on thecommunication links430 or510. The electrical energy supply information may include the monitored voltage component V_Supply(t). The electrical energy supply information may further include the voltage component V_In(t), current components I_In(t), I_Supply(t), and/or phase difference values φ_In(t), φ_Supply(t), as a function of time t. The electrical energy supply status information may also include, for example, the load rating of the LTC transformer.
• The electrical energy supply status information may be provided to theEC system400 at periodic intervals of time, such as, for example, every second, 5 sec., 10 sec., 30 sec., 60 sec., 120 sec., 600 sec., or any other value within the scope and spirit of the disclosure, as determined by one having ordinary skill in the art. The periodic intervals of time may be set by theEC system400 or theER system500. Alternatively, the electrical energy supply status information may be provided to theEC system400 orER system500 intermittently.
• Further, the electrical energy supply status information may be forwarded to theEC system400 in response to a request by theEC system400, or when a predetermined event is detected. The predetermined event may include, for example, when the voltage component V_Supply(t) changes by an amount greater (or less) than a defined threshold value V_{SupplyThreshold}(for example, 130V) over a predetermined interval of time, a temperature of one or more components in theER system500 exceeds a defined temperature threshold, or the like.
ED System300
• TheED system300 includes a plurality ofsmart meters330. TheED system300 may further include at least onecollector350, which is optional. TheED system300 may be coupled to thenetwork170 by means of acommunication link310. Thecollector350 may be coupled to the plurality ofsmart meters330 by means of acommunication link320. Thesmart meters330 may be coupled to theER system500 by means of one or morepower supply lines340, which may also include communication links.
• Eachsmart meter330 is configured to measure, store and report energy usage data by the associatedusers150,160 (shown inFIG. 1). Eachsmart meter330 is further configured to measure and determine energy usage at theusers150,160, including the voltage component V_Meter(t) and current component I_Meter(t) of the electrical power E_Meter(t) used by theusers150,160, as a function of time. Thesmart meters330 may measure the voltage component V_Meter(t) and current component I_Meter(t) of the electrical power E_Meter(t) at discrete times t_s, where s is a sampling period, such as, for example, s=5 sec., 10 sec., 30 sec., 60 sec., 300 sec., 600 sec., or more. For example, thesmart meters330 may measure energy usage every, for example, minute (t_{60 sec}), five minutes (t_{30 sec}), ten minutes (_{t600 sec}), or more, or at time intervals variably set by the smart meter330 (for example, using a random number generator).
• Thesmart meters330 may average the measured voltage V_Meter(t) and/or I_Meter(t) values over predetermined time intervals (for example, 5 min., 10 min., 30 min., or more). Thesmart meters330 may store the measured electrical power usage E_Meter(t), including the measured voltage component V_Meter(t) and/or current component I_Meter(t) as smart meter data in a local (or remote) storage (not shown), such as, for example, a computer readable medium.
• Eachsmart meter330 is also capable of operating in a “report-by-exception” mode for any voltage V_Meter(t), current I_Meter(t), or energy usage E_Meter(t) that falls outside of a target component band. The target component band may include, a target voltage band, a target current band, or a target energy usage band. In the “report-by-exception” mode, thesmart meter330 may sua sponte initiate communication and send smart meter data to theEC system400. The “report-by-exception” mode may be used to reconfigure thesmart meters330 used to represent, for example, the lowest voltages on the circuit as required by changing system conditions.
• The smart meter data may be periodically provided to thecollector350 by means of the communication links320. Additionally, thesmart meters330 may provide the smart meter data in response to a smart meter data request signal received from thecollector350 on the communication links320.
• Alternatively (or additionally), the smart meter data may be periodically provided directly to the EC system400 (for example, the MAS460) from the plurality of smart meters, by means of, for example,communication links320,410 andnetwork170. In this regard, thecollector350 may be bypassed, or eliminated from theED system300. Furthermore, thesmart meters330 may provide the smart meter data directly to theEC system400 in response to a smart meter data request signal received from theEC system400. In the absence of thecollector350, the EC system (for example, the MAS460) may carry out the functionality of thecollector350 described herein.
• The request signal may include, for example, a query (or read) signal and a smart meter identification signal that identifies the particularsmart meter330 from which smart meter data is sought. The smart meter data may include the following information for eachsmart meter130, including, for example, kilo-Watt-hours (kWh) delivered data, kWh received data, kWh delivered plus kWh received data, kWh delivered minus kWh received data, voltage level data, current level data, phase angle between voltage and current, kVar data, time interval data, demand data, and the like.
• Additionally, thesmart meters330 may send the smart meter data to the meter automationsystem server MAS460. The smart meter data may be sent to theMAS460 periodically according to a predetermined schedule or upon request from theMAS460.
• Thecollector350 is configured to receive the smart meter data from each of the plurality ofsmart meters330 via the communication links320. Thecollector350 stores the received smart meter data in a local storage (not shown), such as, for example, a computer readable medium. Thecollector350 compiles the received smart meter data into a collector data. In this regard, the received smart meter data may be aggregated into the collector data based on, for example, a geographic zone in which thesmart meters330 are located, a particular time band (or range) during which the smart meter data was collected, a subset ofsmart meters330 identified in a collector control signal, and the like. In compiling the received smart meter data, thecollector350 may average the voltage component V_Meter(t) values received in the smart meter data from all (or a subset of all) of thesmart meters330.
• TheEC system400 is able to select or alter a subset of all of thesmart meters330 to be monitored for predetermined time intervals, which may include for example 15 minute intervals. It is noted that the predetermined time intervals may be shorter or longer than 15 minutes. The subset of all of thesmart meters330 is selectable and can be altered by theEC system400 as needed to maintain minimum level control of the voltage V_Supply(t) supplied to thesmart meters330.
• Thecollector350 may also average the electrical power E_Meter(t) values received in the smart meter data from all (or a subset of all) of thesmart meters330. The compiled collector data may be provided by thecollector350 to theEC system400 by means of thecommunication link310 andnetwork170. For example, thecollector350 may send the compiled collector data to the MAS460 (or ROC490) in theEC system400.
• Thecollector350 is configured to receive collector control signals over thenetwork170 and communication link310 from theEC system400. Based on the received collector control signals, thecollector350 is further configured to select particular ones of the plurality ofsmart meters330 and query the meters for smart meter data by sending a smart meter data request signal to the selectedsmart meters330. Thecollector350 may then collect the smart meter data that it receives from the selectedsmart meters330 in response to the queries. The selectablesmart meters330 may include any one or more of the plurality ofsmart meters330. The collector control signals may include, for example, an identification of thesmart meters330 to be queried (or read), times) at which the identifiedsmart meters330 are to measure the V_Meter(t) I_Meter(t), E_Meter(t) and/or φ_Meter(t) (φ_Meter(t) is the phase difference between the voltage V_Meter(t) and current I_Meter(t) components of the electrical power E_Meter(t) measured at the identified smart meter330), energy usage information since the last reading from the identifiedsmart meter330, and the like. Thecollector350 may then compile and send the compiled collector data to the MAS460 (and/or ROC490) in theEC system400.
EC System400
• TheEC system400 may communicate with theED system300 and/orER system500 by means of thenetwork170. TheEC system400 is coupled to thenetwork170 by means of one or more communication links410. TheEC system400 may also communicate directly with theER system500 by means of acommunication link430.
• TheEC system400 includes theMAS460, a database (DB)470, a distribution management system (DMS)480, and a regional operation center (ROC)490. TheROC490 may include a computer (ROC computer)495, a server (not shown) and a database (not shown). TheMAS460 may be coupled to theDB470 andDMS480 by means ofcommunication links420 and440, respectively. TheDMS480 may be coupled to theROC490 andER SYSTEM500 by means of thecommunication link430. Thedatabase470 may be located at the same location as (for example, proximate to, or within) theMAS460, or at a remote location that may be accessible via, for example, thenetwork170.
• TheEC system400 is configured to de-select, from the subset of monitoredsmart meters330, asmart meter330 that theEC system400 previously selected to monitor, and select thesmart meter330 that is outside of the subset of monitoredsmart meters330, but which is operating in the report-by-exception mode. TheEC system400 may carry out this change after receiving the sua sponte smart meter data from the non-selectedsmart meter330. In this regard, theEC system400 may remove or terminate a connection to the de-selectedsmart meter330 and create a new connection to the newly selectedsmart meter330 operating in the report-by-exception mode. TheEC system400 is further configured to select any one or more of the plurality ofsmart meters330 from which it receives smart meter data comprising, for example, the lowest measured voltage component V_Meter(t), and generate an energy delivery parameter C_EDbased on the smart meter data received from the smart meter(s)330 that provide the lowest measured voltage component V_Meter(t).
• TheMAS460 may include a computer (not shown) that is configured to receive the collector data from thecollector350, which includes smart meter data collected from a selected subset (or all) of thesmart meters330. TheMAS460 is further configured to retrieve and forward smart meter data to theROC490 in response to queries received from theROC490. TheMAS460 may store the collector data, including smart meter data in a local storage and/or in theDB470.
• TheDMS480 may include a computer that is configured to receive the electrical energy supply status information from thesubstation530. TheDMS480 is further configured to retrieve and forward measured voltage component V_Meter(t) values and electrical power E_Meter(t) values in response to queries received from theROC490. TheDMS480 may be further configured to retrieve and forward measured current component V_Meter(t) values in response to queries received from theROC490. TheDMS480 also may be further configured to retrieve all “report-by-exception” voltages V_Meter(t) from thesmart meters330 operating in the “report-by-exception” mode and designate the voltages V_Meter(t) as one of the control points to be continuously read at predetermined times (for example, every 15 minutes, or less (or more), or at varying times). The “report-by-exception voltages V_Meter(t) may be used to control theEC500 set points.
• TheDB470 may include a plurality of relational databases (not shown). TheDB470 includes a large number of records that include historical data for eachsmart meter330, eachcollector350, eachsubstation530, and the geographic area(s) (including latitude, longitude, and altitude) where thesmart meters330,collectors350, andsubstations530 are located.
• For instance, theDB470 may include any one or more of the following information for eachsmart meter330, including: a geographic location (including latitude, longitude, and altitude); a smart meter identification number; an account number; an account name; a billing address; a telephone number; a smart meter type, including model and serial number; a date when the smart meter was first placed into use; a time stamp of when the smart meter was last read (or queried); the smart meter data received at the time of the last reading; a schedule of when the smart meter is to be read (or queried), including the types of information that are to be read; and the like.
• The historical smart meter data may include, for example, the electrical power E_Meter(t) used by the particularsmart meter330, as a function of time. Time t may be measured in, for example, discrete intervals at which the electrical power E Meter magnitude (kWh) of the received electrical power E_Meter(t) is measured or determined at thesmart meter330. The historical smart meter data includes a measured voltage component V_Meter(t) of the electrical energy E_Meter(t) received at thesmart meter330. The historical smart meter data may further include a measured current component I_Meter(t) and/or phase difference φ_Meter(t) of the electrical power E_Meter(t) received at thesmart meter330.
• As noted earlier, the voltage component V_Meter(t) may be measured at a sampling period of, for example, every five seconds, ten seconds, thirty seconds, one minute, five minutes, ten minutes, fifteen minutes, or the like. The current component I_Meter(t) and/or the received electrical power E_Meter(t) values may also be measured at substantially the same times as the voltage component V_Meter(t).
• Given the low cost of memory, theDB470 may include historical data from the very beginning of when the smart meter data was first collected from thesmart meters330 through to the most recent smart meter data received from the smart meter330s.
• TheDB470 may include a time value associated with each measured voltage component V_Meter(t), current component I_Meter(t), phase component φ_Meter(t) and/or electrical power E_Meter(t), which may include a timestamp value generated at thesmart meter330. The timestamp value may include, for example, a year, a month, a day, an hour, a minute, a second, and a fraction of a second. Alternatively, the timestamp may be a coded value which may be decoded to determine a year, a month, a day, an hour, a minute, a second, and a fraction of a second, using, for example, a look up table. TheROC490 and/orsmart meters330 may be configured to receive, for example, a WWVB atomic clock signal transmitted by the U.S. National Institute of Standards and Technology (NIST), or the like and synchronize its internal clock (not shown) to the WWVB atomic clock signal.
• The historical data in theDB470 may further include historical collector data associated with eachcollector350. The historical collector data may include any one or more of the following information, including, for example: the particularsmart meters330 associated with eachcollector350; the geographic location (including latitude, longitude, and altitude) of eachcollector350; a collector type, including model and serial number; a date when thecollector350 was first placed into use; a time stamp of when collector data was last received from thecollector350; the collector data that was received; a schedule of when thecollector350 is expected to send collector data, including the types of information that are to be sent; and the like.
• The historical collector data may further include, for example, an external temperature value T_Collector(t) measured outside of eachcollector350 at time t. The historical collector data may further include, for example, any one or more of the following for each collector350: an atmospheric pressure value P_Collector(t) measured proximate thecollector350 at time t; a humidity value H_Collector(t) measured proximate thecollector350 at time t; a wind vector value W_Collector(t) measured proximate thecollector350 at time t, including direction and magnitude of the measured wind; a solar irradiant value L_Collector(t) (kW/m²) measured proximate thecollector350 at time t; and the like.
• The historical data in theDB470 may further include historical substation data associated with eachsubstation530. The historical substation data may include any one or more of the following information, including, for example: the identifications of the particularsmart meters330 supplied with electrical energy E_Supply(t) by thesubstation530; the geographic location (including latitude, longitude, and altitude) of thesubstation530; the number of distribution circuits; the number of transformers; a transformer type of each transformer, including model, serial number and maximum Megavolt Ampere (MVA) rating; the number of voltage regulators; a voltage regulator type of each voltage regulator, including model and serial number; a time stamp of when substation data was last received from thesubstation530; the substation data that was received; a schedule of when thesubstation530 is expected to provide electrical energy supply status information, including the types of information that are to be provided; and the like.
• The historical substation data may include, for example, the electrical power E_Supply(t) supplied to each particularsmart meter330, where E_Supply(t) is measured or determined at the output of thesubstation530. The historical substation data includes a measured voltage component V_Supply(t) of the supplied electrical power E_Supply(t), which may be measured, for example, on the distribution bus (not shown) from the transformer. The historical substation data may further include a measured current component I_Supply(t) of the supplied electrical power E_Supply(t). As noted earlier, the voltage component V_Supply(t), the current component I_Supply(t), and/or the electrical power E_Supply(t) may be measured at a sampling period of, for example, every five seconds, ten seconds, thirty seconds, a minute, five minutes, ten minutes, or the like. The historical substation data may further include a phase difference value φ_Supply(t) between the voltage V_Supply(t) and current I_Supply(t) signals of the electrical power E_Supply(t), which may be used to determine the power factor of the electrical power E_Supply(t) supplied to thesmart meters330.
• The historical substation data may further include, for example, the electrical power E_In(t) received on theline520 at the input of thesubstation530, where the electrical power E_In(t) is measured or determined at the input of thesubstation530. The historical substation data may include a measured voltage component V_In(t) of the received electrical power E_In(t), which may be measured, for example, at the input of the transformer. The historical substation data may further include a measured current component I_In(t) of the received electrical power E_In(t). As noted earlier, the voltage component V_In(t), the current component I_In(t), and/or the electrical power E_In(t) may be measured at a sampling period of, for example, every five seconds, ten seconds, thirty seconds, a minute, five minutes, ten minutes, or the like. The historical substation data may further include a phase difference φ_In(t) between the voltage component V_In(t) and current component I_In(t) of the electrical power E_In(t). The power factor of the electrical power E_In(t) may be determined based on the phase difference φ_In(t).
• According to an aspect of the disclosure, theEC system400 may save aggregated kW data at the substation level, voltage data at the substation level, and weather data to compare to energy usage persmart meter330 to determine the energy savings from theVCC system200, and using linear regression to remove the affects of weather, load growth, economic effects, and the like, from the calculation.
• In theVCC system200, control may be initiated from, for example, theROC computer495. In this regard, acontrol screen305 may be displayed on theROC computer495, as shown, for example, inFIG. 3. Thecontrol screen305 may correspond to data for a particular substation530 (for example, the TRABUE SUBSTATION) in theER system500. TheROC computer495 can control and override (if necessary), for example, thesubstation530 load tap changing transformer based on, for example, the smart meter data received from theED system300 for theusers150,160. TheED system300 may determine the voltages of the electrical power supplied to theuser locations150,160, at predetermined (or variable) intervals, such as, e.g., on average each 15 minutes, while maintaining the voltages within required voltage limits.
• For system security, thesubstation530 may be controlled through the direct communication link430 from theROC490 and/orDMS480.
• Furthermore, an operator can initiate a voltage control program on theROC computer490, overriding the controls, if necessary, and monitoring a time it takes to read the user voltages V_Meter(t) being used for control of, for example, the substation LTC transformer (not shown) in theER system500.
• FIG. 4 shows an example of a voltage control and conservation (VCC) process according to principles of the disclosure. The VCC process may be carried out by, for example, but not limited to, theVCC system200 shown inFIG. 2.
• Referring toFIGS. 2 and 4, a target voltage band V_Band-nmay be determined for the voltage component V_Meter(t) of the electrical power E_Meter(t) received and measured at the smart meters330 (Step610). The target voltage band V_Band-nmay be determined by setting a voltage set point value V_SPand a permissible voltage deviation range ΔV according to the expression [1] V_Band-n=V_SP+ΔV. For instance, the voltage set point V_SPvalue may be set to 120V with a permissible voltage deviation of ΔV of five percent (+/−5%) for the target voltage band V_Band-1. In this example, the target voltage band V_Band-nwill be from about 114V (i.e., 120V−(120V.times.0.050)) to about 126V (i.e., 120V+(120V.times.0.050)).
• The voltage component V_Supply(t) and electrical power E_Supply(t) values measured atsubstation530 may be retrieved from the DMS480 (Step620). The current, or most recent voltage component V_Meter(t) and electrical power E_Meter(t) values received and measured at the selected subset of the plurality ofsmart meters330 may be retrieved from the MAS460 (or a local storage, such as, for example, a computer readable medium, in the ROC490) (Step630). The current, or most recent voltage component V_Meter(t) and electrical power E_Meter(t) values may have been measured by the select subset ofsmart meters330 and forwarded to theMAS460 via thecollector350, as described above.
• Alternatively, the current, or most recent voltage component V_Meter(t) and electrical power E_Meter(t) values may have been retrieved directly from thecollector350 or the selected subset of the smart meters330 (Step630).
• The current, or most recent voltage component V_Meter(t) and electrical power E_Meter(t) values may have been measured at the selected subset ofsmart meters330 in response to a smart meter data request signal received from thecollector350. Thecollector350 may have sent the smart meter data request signal in response to a collector control signal received from the MAS460 (or the ROC490).
• The current, or most recent voltage component V_Meter(t) values may be averaged for the selected number ofsmart meters330 to determine an average voltage component V_Meter-Avg(t) value for the electrical power delivered to the selectedsmart meters330. This average voltage component V_Meter-Avg(t) value may then be compared to the target voltage band V_Band-nto determine whether the average voltage component V_Meter-Avg(t) value is within the target voltage band V_Band-n(Step650).
• If the average voltage component V_Meter-Avg(t) value is outside of the target voltage band V_Band-n, then a determination is made to change the set point voltage V_SPof the voltage component V_Supply(t) output by the substation530 (YES at Step660). Energy delivery parameters C_EDmay be generated and sent to thesubstation530 to adjust the set point voltage V_SPof the output voltage component V_Supply(t) (Step670). A new voltage set point voltage V^SPvalue may be calculated by theDMS480. Where a LTC transformer is used, the voltage set point voltage V_SPvalue may be increased (or decreased) at a maximum rate of, for example, one volt about every, for example, fifteen minutes (Note: for example, a 0.625% voltage change per step in a LTC transformer). It is noted that the voltage set point voltage V_SPvalue may be increased (or decreased) at a rate of, for example, a fraction of a volt, or multiple volts at one time. The energy delivery parameters C_EDmay include, for example, load tap coefficients. The set point voltage V_SPmay be adjusted up (or down) by, for example, a fraction of a Volt (e.g., 0.01V, 0.02V, . . . , 0.1V, 0.2V, . . . , 1.0V, . . . , or the like).
• Furthermore; when either the V_Supplyt) or the V_Meter-Avg(t) voltage components reach or fall below a predetermined minimum voltage range (for example, about 118V to about 119V), the set point voltage V_SPmay be increased. When the voltage set point V_SPis raised, the V_Supply(t) or the V_Meter-Avg) voltage components should remain in a higher voltage band for, e.g., twenty-four hours before the voltage set point V_SPmay be lowered again.
• If the average voltage component V_Meter-Avgvalue is within the target voltage band V_Band-n, then a determination is made not to change the set point voltage V_SPof the voltage component V_Supply(t) output by the substation530 (NO at Step660), and a determination may be made whether to end the VCC process (Step680). If a determination is made not to end the VCC process (NO at Step680), the VCC process repeats.
• According to an aspect of the disclosure, a computer readable medium is provided containing a computer program, which when executed on, for example, the ROC495 (shown inFIG. 2), causes the VCC process according toFIG. 4 to be carried out. The computer program may be tangibly embodied in the computer readable medium, comprising a code segment or code section for each of theSteps610 through680.
• FIG. 5A shows an example of a process for monitoring the voltage component V_Meter(t) and electrical power E_Meter(t) received and measured at selectedsmart meters330, according to an aspect of disclosure.
• Referring toFIGS. 2 and 5A, initially a subset ofsmart meters330 is selected from thesmart meters330 that are coupled to thepower lines340, which are supplied with the electrical energy E_Supply(t) out from the substation530 (Step710). The subset may include, for example, one or more (or all) of thesmart meters330 that are selected randomly or based on predetermined criteria live predetermined criteria may include, for example, historical smart meter data, weather conditions, geographic area, solar irradiation, historical energy usage associated with particularsmart meters330, and the like. Thesmart meters330 may be selected, for example, at theROC490 orMAS460.
• A schedule may be generated to obtain smart meter data from the selected subset of smart meters330 (Step720). The schedule may include, for example, measuring the received voltage component V_Meter(t) and electrical power E_Meter(t) every, for example, five seconds, ten seconds, thirty seconds, one minute, five minutes, ten minutes, fifteen minutes, or the like, at the selected subset ofsmart meters330. The generated schedule is provided to thecollector350 that is associated with the selected subset ofsmart meters330 as part of a collector control signal (Step730). The collector control signal may be generated at, for example, theROC490 orMAS460 and sent to thecollector350 viacommunication link410 andnetwork170.
• Thecollector350, based on the provided collector control signal or a previously received schedule, may send a smart meter data request signal to the selected subset ofsmart meters330 via communication links320. The smart meter data request signal may include, for example, the schedule provided in the collector control signal. The schedule may be stored at the selected subset ofsmart meters330 and used by thesmart meters330 to control monitoring and reporting of the received voltage component V_Meter(t) and electrical power E_Meter(t) for the associated user150 (160).
• Thecollector350 receives the reported smart meter data, including the voltage component V_Meter(t) and electrical energy E_Meter(t) for the associated user150 (160), from the selected subset ofsmart meters330 via communication links320. Thecollector350 compiles the received smart meter data, generating collector data and sending the collector data to theEC system400.
• The collector data is received from the collector350 (Step740) and stored locally (or remotely) in the EC system400 (Step750). In particular, the received collector data is stored locally in, for example, theROC490, theMAS460 and/or theDB470.
• According to an aspect of the disclosure, a computer readable medium is provided containing a computer program, which when executed on, for example, the ROC495 (shown inFIG. 2), causes the process for monitoring the voltage component and electrical power to be carried out according toFIG. 5A. The computer program may be tangibly embodied in the computer readable medium, comprising a code segment or code section for each of theSteps710 through750.
• FIG. 5B shows an example of a process for selecting asmart meter330 operating in a report-by-exception mode and de-selecting a previously selected smart meter, according to principles of the disclosure.
• Referring toFIG. 2 andFIG. 5B, theEC system400 is configured to listen or monitor for sua sponte smart meter data that may be received from one or more of thesmart meters330 operating in the report-by-exception mode (Step760). If sua sponte smart meter data is received from a particular smart meter330 (YES, at Step760), then theEC system400 will proceed to select that particular smart meter330 (Step765) and create a communication link to the smart meter330 (Step770), otherwise theEC system400 continues to monitor for sua sponte smart meter data (NO, at Step760). TheEC system400 de-selects a previously selected smart meter330 (Step775), which was selected as part of the subsetsmart meters330 to be monitored from the plurality ofsmart meters330, and terminates the communication link to the de-selected smart meter330 (Step780). TheEC system400 may use the sua sponte smart meter data to determine a voltage set point and provide the voltage set point to theER system500 to adjust the voltage set point (Step785).
• According to an aspect of the disclosure, a computer readable medium is provided containing a computer program, which when executed on, for example, the ROC495 (shown inFIG. 2), causes the process for selecting asmart meter330 operating in a report-by-exception mode and de-selecting a previously selected smart meter. The computer program may be tangibly embodied in the computer readable medium, comprising a code segment or code section for each of theSteps760 through785.
• FIG. 6 shows an example of a graph of a voltage of electric power supplied tousers150,160, versus a time of day, according to principles of the disclosure. In particular, theupper waveform805 shows an example of voltage fluctuations in the electrical power delivered to theusers150,160, without theVCC system200. Thelower waveform808 shows an example of voltage fluctuations in the electric power delivered tousers150,160, with theVCC system200. Thearea807 between theupper waveform805 andlower waveform808 corresponds to the energy saved using theVCC system200.
• As seen inFIG. 6, thelower waveform808 includes a tighter range (lower losses) of voltage fluctuations compared to theupper waveform805, which experiences higher voltage fluctuations and increased losses, resulting in substantially reduced power losses for thelower waveform808. For example, thevoltage805 may fluctuate between about 114V and about 127V. Whereas, in theVCC system200, thevoltage waveform808 fluctuation may be reduced to, for example, between about 114V and about 120V. As seen in the graph, theVCC system200 may provide conservation through, for example, avoided energy imports and behind-the-meter savings. Further, theVCC system200 may provide high confidence level of savings without having to depend on the actions of theusers150,160.
• FIG. 7 shows an example of awaveform810 of substation voltages V_Supply(t) of electric power produced by, for example, an LTC transformer at thesubstation530, which may be associated with, for example, the information displayed on thecontrol screen305 shown inFIG. 3. Awaveform820 shows an average of, for example, twenty lowest level (or worst case) user voltages V_Meter(t) (for example, the ten worst voltages on one distribution circuit averaged with the ten worst voltages on another distribution circuit) monitored at any one time on two distribution circuits that supply, for example, six-thousand-four-hundredusers150,160 (shown inFIG. 1) with electrical power during a period of time. In particular, thegraph810 shows an example of voltage fluctuations (for example, an average ofvoltage812 fluctuations andvoltage814 fluctuations on the pair of circuits, respectively) in the electrical power produced by the substation530 (for example, the TRABUE SUBSTATION inFIG. 3) and thevoltage820 fluctuations (for example, on the pair of circuits) in the electrical power delivered to theusers150,160.
• Thewaveforms810 and820 prior to time t₀show an example of voltage fluctuations in the electrical power E_Supply(t) supplied by thesubstation530 and electrical power E_Meter(t) received by theusers150,160, without theVCC system200. Thewaveforms810 and820 after time t₀show an example of voltage fluctuations in the electrical power E_Supply(t) supplied by thesubstation530 and electrical power E_Meter(t) received by theusers150,160, with theVCC system200. As seen inFIG. 7, before voltage control was applied (i.e., before t₀), thevoltages812,814 (with an average voltage signal810) of the electrical power E_Supply(t) supplied by thesubstation530 generally fluctuated between, for example, about 123V and about 126V; and thevoltage waveform820 of the electrical power E_Meter(t) received by theusers150,160, generally fluctuated between, for example, about 121V and 124V. After voltage control was applied, thevoltage waveforms812,814 (810) generally fluctuated between, for example, about 120V and about 122V, and thevoltage waveform820 generally fluctuated between, for example, about 116V and about 121V. Accordingly, theVCC system200 is able to operate theusers150,160, in a lower band level.
• Energy savings807 (shown inFIG. 6) that result from operation of theVCC system200, according to principles of the disclosure, may be measured and/or validated by measuring the voltage component V_Supply(t) and electrical power E_Supply(t) levels of electric power supplied by thesubstation530 relative to the corresponding reference voltage set point V_SP(1) value. In the example shown inFIG. 7, the voltage V_Supply(t) and electrical energy E_Supply(t) levels may be measured at the transformer output (not shown) where the voltage control may be implemented. However, the measurement may be performed at any point where measurements could be made for the transmission or distribution systems.
• FIG. 8 shows an example of data collected (including voltage and energy measurement) hourly by the DMS480 (shown inFIG. 2), before time t₀(shown inFIG. 7), when voltage control is not carried out in theVCC system200. As seen inFIG. 8, the collected data may include, for example, a date, a time (hour:minute:second), a power level (MWatt), a reactive power level (MVAr), a voltage (V), an apparent power level (MVA), a power factor (PF), loss factor, and loss FTR, of the electrical power E_Supply(t) output by thesubstation530.
• FIG. 9 shows an example of data collected (including voltage and energy measurement) hourly by the DMS480 (shown inFIG. 2), after time t₀(shown inFIG. 7), when voltage control is carried out in theVCC system200. As seen inFIG. 9, the collected data may include, for example, a date, a time (hour:minute:second), a power level (MWatt), a reactive power level (MVAr), a voltage (V), an apparent power level (MVA), a power factor (PF), load financial transmission rights (FIR), and loss FTR, of the electrical power E_Supply(t) output by thesubstation530 with voltage control carried out by theVCC system200.
• Comparing the data inFIG. 8 to data ofFIG. 9, the voltage V_Supply(t) and electrical power E_Supply(t) measurements show the substantial impact of lowering voltage on the electric power usage by, for example,users150,160. In this regard, the hourly data at a transformer (not shown) in the substation530 (shown inFIG. 2) may be saved hourly. Voltage control and/or conservation may be carried according to the principles of the disclosure, and the energy use before (FIG. 8) and after (FIG. 9) implementation of theVCC system200 may be compared at the two different voltage levels along the distribution circuit (for example, from or in the substation530). In the examples shown inFIGS. 8 and 9, the before voltages may range from, for example, about 123V to about 125V, and the after voltages may range from, for example, about 120V to about 177V.
• As shown inFIG. 7, theVCC system200 can monitor the twenty worst case voltages supplied by the distribution circuits and control the source bus voltage V_SP(t) to maintain the operation in the lower band, as shown, for example, inFIG. 6. TheVCC system200 can also reselect thesmart meters330 used for the 20 worse case voltages based on, for example, the information received from theEC system400 “report-by-exception” monitoring of voltage. TheVCC system200 may select these newsmart meters330 from the total number ofsmart meters330 connected to thesubstation530.
• The voltage V_Supply(t) and electrical power E_Supply(t) data shown inFIGS. 8 and 9 may be arranged by hour and averaged over twenty-four hour periods, retaining the correct average of voltage to electrical power (MW) by calculating the voltage to electrical power (MW) value for each hour, adding for the twenty-four hours, calculating the weighted twenty-four hour voltage using the average hourly electrical power (MW) value and the total twenty-four hour electrical power (MW) to Voltage ratio for the day. This may produce one value for average electrical power (MW) per hour for a twenty-four hour period and a weighted voltage associated with this average electrical power usage.
• FIG. 10 shows an example of calculation data for hours 1-5 and the average for the full twenty-four hours in the example ofFIGS. 7-9.
• FIG. 11 shows an example where data may be collected for weather variables for the days before and after voltage control and/or conservation by theVCC system200 according to the disclosure. In particular,FIG. 11 shows the data collected from the National Weather Service for, for example, Richmond International Airport, the nearest weather station location to the TRABUE SUBSTATION (shown inFIG. 3). The data shown is for the same period as the example ofFIG. 7. The data shown inFIG. 11 may be used to eliminate as much of the changes in power, other than those caused by voltage, to provide as accurate a measurement as possible.
• FIG. 12 shows an example of an application of the paired test analysis process, according to principles of the disclosure. As seen, kW usage per customer per day in the time period from May to January when, for example, the VCC is in the OFF mode, is compared to kW usage per customer per day in the time period from January to November when, for example, the VCC is the ON mode. The Trabue Load growth demonstrates the process of pairing the test days fromstate 1 tostate 2. Days from thepair 1 are picked from the May through January time period with voltage conservation turned OFF and matched with the days from thepair 2 period from, for example, January through November. The match may be based on the closest weather, season, day type, and relative humidity levels to remove as many other variables as possible, except for the change in voltage. Because the data is collected over a long period of time, where economic and growth can also impact the comparison of the characteristics of growth or economic decline are removed by using the kW-per-customer data to remove effects in customer energy usage increases and decreases and a monthly linear regression model to remove the growth or economic decline correlated to the month with the weather variables removed.
• FIG. 13 shows an example of a scatterplot of a total power per twenty-four hours versus heating degree day. In this regard, the voltage and electrical power (MW) per hour may be recorded, and average voltage and electrical power (MW) per hour determined for a twenty-four hour period. The scatterplot may be used to predict the power requirements for the next day using the closest power level day from the historical data stored in DB470 (shown inFIG. 2). The calculation may use as inputs the change in the variables from the nearest load day to the day being calculated and the output may be the new load level. Using these inputs and a standard linear regression calculation a model may be built for the historical data The regression calculation may include, for example, the following expression [2]:
• 
  E_{Total/Customer}=−4.54−0.260D_Season−0.213D_Type+0.0579H+0.0−691V_Avg+0.00524D_Month  [2]
• where: E_Totalis a total power for a twenty-four hour period per customer for a particular day; D_Typeis a day type (such as, for example, a weekend, a weekday, or a holiday) of the particular day, D_Seasonis one of four seasons corresponding to the particular day in the calendar year; D_Monthis the particular day in the month; H is a Heating Degree Day level for the particular day; and V is the V_Avgaverage voltage supplied per customer for the particular day.
• The data shown in the example ofFIG. 13 includes historic data for a 115 day period, before theVCC system200 is implemented according to principles of the disclosure. The example shown inFIG. 12 may correspond to a winter season for TRABUE SUBSTATION loads. As seen inFIG. 13, the model may be used represent the change in power level from one day to the next that is not related to the weather, growth, and economic variables in the linear regression expression [2].
• The historical data may be adjusted to match the heating degree day level for the measurements taken after the voltage control and/or conservation is carried out by theVCC system200. For example, referring toFIG. 11, a heating degree day of 19 may be read for a particular day, Feb. 1, 2009. The historical data may be searched in theDB470 for all days with heating degree levels of 19. For example, two days in December may be found with the same heating degree day levels—for example, December 1 and 17. The linear regression model expression [2] for the historical data may be used to adjust the variables for December 1 and 17 to the same values as the data taken on Feb. 1. 2009, This may provide as close a match between the historical (operating at the higher voltage level) and Feb. 1, 2009 (operating at the lower voltage level). The calculation of (change in MW)/(change in Voltage) may be made from the high voltage to the low voltage operation. This may become one data point for the statistical analysis.
• This process may be repeated for all measurements taken after the voltage conservation is turned on and compared to all similar days in the historical data taken for the matching season and other weather conditions. This may produce, for example, one-hundred-fifteen data points from, for example, 115 days of operation matched with all of the historical matching data. The resulting statistical analysis of this data is shown inFIGS. 13-14.
• The normality of the data may be validated using the Anderson-Darling Normality test. In the case of the example ofFIGS. 13 and 14, the P-Value may be 0.098, which may be well above the required value of 0.01, thereby demonstrating that the data may be normal with an approximately 99% confidence level, as shown inFIG. 14. This allows the application of a one sample T test to demonstrate the average of the mean value of the change in electrical power (MW) to change in voltage. The test may be performed to evaluate the statistical significance of the average value being above, for example, about 1.0. As shown inFIG. 14 the test may demonstrate an approximately 99% confidence level that the savings in power to reduction in voltage may be above about 1.0% per 1% of voltage change. Using this type of statistical method continuous tracking of the energy saving improvement can be accomplished and recorded in kW/customer saved per day or aggregated to total kW saved for the customers connected to thesubstation530.
• FIG. 15 shows an alternative example of a scatterplot of a total power per twenty-four hours versus heating degree day. In this regard, the voltage and electrical power (MW) per hour may be recorded, and average voltage and electrical power (MW) per hour determined for a twenty-four hour period. The scatterplot may be used to predict the power requirements for the next day using the closest power level day from the historical data stored in DB470 (shown inFIG. 2). The calculation may use as inputs the change in the variables from the nearest load day to the day being calculated and the output may be the new load level. Using these inputs and a standard linear regression calculation a model may be built for the historical data. The regression calculation may include, for example, the following expression [3]:
• 
  E_Total=(−801+0.069Y+0.0722D_Type+0.094D_Year+0.0138D_Month+0.126T_max+0.131T_min+9.84T_avg+10.1H−10.3C+0.251P_Std)−(0.102T_max-d−0.101T_min-d+0.892T_avg-d+0.693H_d−0.452C_d−0.025P_R+0.967E_{Total/Previous})   [3]
• where: E_Totalis a total power for a twenty-four hour period for a particular day; Y is a calendar year of the particular day; D_Typeis a day type (such as, for example, a weekend, a weekday, or a holiday) of the particular day; D_Yearis the particular day in the calendar year; D_Monthis the particular day in the month; T_maxis a maximum temperature for the particular day; T_minis minimum temperature for the particular day; T_avgis the average temperature for the particular day; H is a Heating Degree Day level for the particular day; C is a Cooling Degree Day level; P_STDis a barometric pressure for the particular day; T_max-dis a maximum temperature for a closest comparison day to the particular day; T_min-dis minimum temperature for the closest comparison day to the particular day; T_avg-dis the average temperature for the closest comparison day to the particular day; H_dis a Heating Degree Day level for the closest comparison day to the particular day; C_dis a Cooling Degree Day level for the closest comparison day to the particular day; P_Ris a Barometric pressure for the closest comparison day to the particular day; and E_{Total/Previous}is the total average hourly usage in MW on the closest comparison day to the particular day. The data shown in the example ofFIG. 15 includes historic data for a fifty day period, before theVCC system200 is implemented according to principles of the disclosure. The example shown inFIG. 15 may correspond to a winter season for TRABUE SUBSTATION loads. As seen inFIG. 15, the model may represent 99.7% of the change in power level from one day to the next using the variables in the linear regression expression [3].
• The historical data may be adjusted to match the heating degree day level for the measurements taken after the voltage control and/or conservation is carried out by theVCC system200. For example, referring toFIG. 11, a heating degree day of 19 may be read for a particular day, Feb. 1, 2009. The historical data may be searched in theDB470 for all days with heating degree levels of 19. For example, two days in December may be found with the same heating degree day levels—for example, December 1 and 17. The linear regression model expression [3] for the historical data may be used to adjust the variables for December 1 and 17 to the same values as the data taken on Feb. 1, 2009. This may provide as close a match between the historical (operating at the higher voltage level) and Feb. 1, 2009 (operating at the lower voltage level). The calculation of (change in MW)/(change in Voltage) may be made from the high voltage to the low voltage operation. This may become one data point for the statistical analysis.
• This process may be repeated for all measurements taken after the voltage conservation is turned on and compared to all similar days in the historical data taken for the matching season and other weather conditions. This may produce, for example, seventy-one data points from, for example, thirty days of operation matched with all of the historical matching data. The resulting statistical analysis of this data is shown inFIG. 17.
• The normality of the data may be validated using the Anderson-Darling Normality test. In the case of the example ofFIGS. 6 and 7, the P-Value may be 0.305, which may be well above the required value of 0.02, thereby demonstrating that the data may be normal with an approximately 98% confidence level, as shown inFIG. 17. This allows the application of one sample T test to demonstrate the average of the mean value of the change in electrical power (MW) to change in voltage. The test may be performed to evaluate the statistical significance of the average value being above about 0.8. As shown inFIG. 17 the test may demonstrate an approximately 98% confidence level that the savings in power to reduction in voltage may be above about 0.8% per 1% of voltage change.
• While the disclosure has been described in terms of exemplary embodiments, those skilled in the art will recognize that the disclosure can be practiced with modifications in the spirit and scope of the appended claims. These examples are merely illustrative and are not meant to be an exhaustive list of all possible designs, embodiments, applications or modifications of the disclosure.

Claims (161)

What is claimed as new and desired to be protected by Letters Patent of the United States is:

1. An electric power control system for an electric power grid configured to supply electric power from a supply point to a plurality of consumption locations, the system comprising:

a plurality of sensors, wherein each sensor is located at a respective one of a plurality of distribution locations on the electric power grid at or between the supply point and at least one of the plurality of consumption locations, and wherein each sensor is sensing at least one component of the supplied electric power received by the sensor at the respective distribution location and generating measurement data based on the sensed component;

a controller configured to receive measurement data from a subset of the plurality of sensors, wherein the subset includes more than one and fewer than all of the plurality of sensors receiving the supplied electric power, wherein the controller is further configured to add to the subset at least one other sensor in response to receiving a signal indicating that the component of the suppled electric power sensed by the at least one other sensor is outside a predetermined band; and

an adjusting device configured to adjust a component of the electric power supplied at the supply point based on the measurement data from the subset of the plurality of sensors.

2. The system ofclaim 1, wherein the subset of sensors comprises the bellwether sensors of the plurality of sensors that have the lowest sensed measured component of electric power.

3. The system ofclaim 1, wherein the measured components of electric power comprises at least one of: a voltage; a current; and a phase.

4. The system ofclaim 1, wherein the components of electric power adjusted by the adjusting device comprises at least one of: a voltage; a current; and a phase.

5. The system ofclaim 1, wherein the subset includes only the sensors sensing the voltages.

6. The system ofclaim 5, wherein the sensors sensing worst case voltages comprise the sensors sensing the lowest level voltages.

7. The system ofclaim 1, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors.

8. The system ofclaim 7, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors receiving the supplied electric power.

9. The system ofclaim 1, wherein the consumption locations are user locations and the plurality of sensors comprises a plurality of smart meters.

10. The system ofclaim 1, wherein the consumption locations are user locations and the electric power grid is an electric power transmission and distribution grid.

11. The system ofclaim 10, wherein the subset includes about twenty sensors on the electric power grid.

12. The system ofclaim 10, wherein the subset includes about ten sensors on a distribution circuit of the electric power grid.

13. The system ofclaim 12, wherein the electric power grid comprises two distribution circuits providing electric power to about 6400 user locations.

14. The system ofclaim 1, wherein the adjusting device comprises a voltage adjusting device.

15. The system ofclaim 14, wherein the voltage adjusting device comprises a load tap change transformer that adjusts the voltage of the electric power supplied at the supply point at a substation level based on a load tap change coefficient.

16. The system ofclaim 14, wherein the voltage adjusting device comprises a voltage regulator that adjusts the voltage of the electric power supplied at the supply point based on the measurement data.

17. The system ofclaim 16, wherein the voltage regulator comprises a circuit regulator that adjusts the voltage of the electric power supplied at the supply point at a line regulator level based on the measurement data.

18. The system ofclaim 1, wherein at least one sensor of the subset is located at a user location.

19. The system ofclaim 1, wherein at least one of the plurality of sensors is located on the electric power grid between the supply point and at least one of the user locations.

20. The system ofclaim 1, wherein the supply point is at a transformer at a substation.

21. The system ofclaim 1, further comprising at least one sensor target electric power component band including a plurality of sensor target electric power component bands, each of the plurality of sensor electric power component voltage bands corresponding to a respective sensor.

22. The system ofclaim 1, wherein the sensors of the subset are selected randomly.

23. The system ofclaim 1, wherein the sensors of the subset are selected based on predetermined criteria.

24. The system ofclaim 23, wherein the predetermined criteria includes historical sensor data.

25. The system ofclaim 23, wherein the predetermined criteria includes historical energy usage associated with particular sensors.

26. The system ofclaim 23, wherein the predetermined criteria includes weather conditions, geographic area, or solar irradiation.

27. The system ofclaim 23, wherein the voltage controller receives measurement data from each sensor at time intervals having a predetermined length.

28. The system ofclaim 23, wherein the voltage controller receives measurement data from each sensor of the subset at time intervals having a predetermined length.

29. The system ofclaim 28, wherein the time intervals each have a length of approximately 5 seconds.

30. The system ofclaim 28, wherein the time intervals each have a length of approximately 10 seconds.

31. The system ofclaim 28, wherein the time intervals each have a length of approximately 30 seconds.

32. The system ofclaim 28, wherein the time intervals each have a length of approximately 1 minute.

33. The system ofclaim 28, wherein the time intervals each have a length of approximately 5 minutes.

34. The system ofclaim 28, wherein the time intervals each have a length of approximately 10 minutes.

35. The system ofclaim 28, wherein the time intervals each have a length of approximately 15 minutes.

36. The system ofclaim 28, wherein the plurality of time intervals during which the controller receives measurement data from each sensor of the subset are continuous.

37. The system ofclaim 27, wherein the plurality of time intervals during which the controller receives measurement data from each sensor are intermittent.

38. The system ofclaim 27, wherein the plurality of time intervals during which the controller receives measurement data from each sensor of the subset are intermittent.

39. The system ofclaim 27, wherein the time intervals have an average length of 15 minutes.

40. The system ofclaim 28, wherein the time intervals each have a length of less than 1.5 minutes.

41. The system ofclaim 1, wherein the voltage controller receives measurement data from a sensor in response to a request by the controller.

42. The system ofclaim 1, wherein the voltage controller receives measurement data from a sensor when a predetermined event is detected.

43. The system ofclaim 1, wherein the controller is further configured to generate an energy delivery parameter based on the measurement data received from the subset and the adjusting device is configured to adjust a component of the electric power supplied at the supply point based on the energy delivery parameter.

44. The system ofclaim 43 wherein the controller is further configured to adjust the energy delivery parameter when an electric power component at a user location is outside a predetermined electric power component range, the predetermined component range being based on a safe nominal operating range.

45. The system ofclaim 43, wherein the controller is further configured to adjust the energy delivery parameter when an electric power component at a user location is below a predetermined minimum electric power component value, the predetermined minimum value being based on a safe nominal operating range.

46. The system ofclaim 43, wherein the controller is further configured to determine an average electric power component value by averaging the measurement data received from the subset, and generate the energy delivery parameter based on the determined average electric power component value.

47. The system ofclaim 46, wherein the controller is further configured to adjust the energy delivery parameter when the determined average electric power component value is outside a predetermined electric power component range, the predetermined component range being based on a safe nominal operating range.

48. The system ofclaim 46, wherein the controller is further configured to adjust the energy delivery parameter when the determined average electric power component value is below a predetermined minimum electric power component value, the predetermined minimum value being based on a safe nominal operating range.

49. The system ofclaim 43, wherein the controller is further configured to generate an energy delivery parameter based on a comparison of the measurement data received from the subset to a controller target voltage band.

50. The system ofclaim 43, wherein the energy delivery parameter is generated such that the electric power component remains within a target component band, the target component band being a lower band of a safe nominal operating range.

51. The system ofclaim 1, wherein at least one other sensor of the plurality of sensors that is not included in the subset is further configured to send a respective reporting signal to the controller when the electric power component sensed by the sensor is determined to be outside of a respective sensor target component band.

52. The system ofclaim 1, wherein the consumption locations are user locations and a substation includes the supply point configured to supply electrical power to a plurality of user locations.

53. The system ofclaim 1, wherein the energy delivery parameter is generated such that the electric power component at each consumption location remains within a user target component band, the user target component band being a lower band of a safe nominal operating range.

54. The system ofclaim 45, wherein the component is voltage and the minimum value is about 114V.

55. The system ofclaim 45, wherein the component is voltage and the minimum value is about 111V.

56. The system ofclaim 45, wherein the component is voltage and the minimum value is about 116V.

57. The system ofclaim 45, wherein the component is voltage and the safe nominal operating range is between about 114V and about 126V and the user target voltage band is between about 114V and about 120V.

58. The system ofclaim 45, wherein the component is voltage and the safe nominal operating range is between about 114V and about 126V and the user target voltage band is between about 116V and about 121V.

59. The system ofclaim 45, wherein the component is voltage and the safe nominal operating range is between about 111V and about 129V the user target voltage band is between about 111V and about 120V.

60. The electric power and control system ofclaim 1, wherein the electric power control system is a voltage control and energy conservation system, the electric power grid is an electric power transmission and distribution grid, and the plurality of consumption locations are a plurality of user locations, the system further comprising:

a substation including a supply point configured to supply electrical power to a plurality of user locations,

wherein the at least one component of the supplied electric power is voltage;

wherein the controller is a voltage controller and wherein the subset includes substantially fewer than all of the plurality of sensors, and to generate an energy delivery parameter based on a comparison of the measurement data received from the subset to a controller target voltage band;

wherein the adjusting device is a voltage adjusting device configured to adjust a voltage of the electric power supplied at the supply point based on the energy delivery parameter;

wherein the energy delivery parameter is generated such that the voltage at each user location remains within a user target voltage band, the user target voltage band being a lower band of a safe nominal operating range; and

wherein at least one other sensor of the plurality of sensors that is not included in the subset is further configured to send a respective reporting signal to the voltage controller when the voltage sensed by the sensor is determined to be outside of a respective sensor target voltage band.

61. The system ofclaim 60, wherein the subset of sensors comprises the sensors of the plurality of sensors that have the lowest sensed voltages.

62. The system ofclaim 60, wherein the voltage adjusting device comprises:

a load tap change transformer that adjusts the voltage of the electric power supplied at the supply point based on a load tap change coefficient; or

a voltage regulator that adjusts the voltage of the electric power supplied at the supply point based on the energy delivery parameter.

63. The system ofclaim 60, wherein the voltage controller is further configured to determine an average voltage by averaging the measurement data received from the subset, and generate the energy delivery parameter based on the determined average voltage.

64. The system ofclaim 63, wherein the voltage controller is further configured to adjust the energy delivery parameter when one of the voltage at a user location or the determined average voltage is below a predetermined minimum voltage value, the predetermined minimum voltage value being based on the safe nominal operating range.

65. The system ofclaim 60, wherein the voltage controller is configured to:

store historical component data that includes at least one of aggregated energy component data at a substation level, voltage component data at a substation level, and weather data;

determine energy usage at each of the plurality of sensors;

compare the historical component data to the determined energy usage; and

determine energy savings attributable to the system based on the results of the comparison of the historical component data to the determined energy usage.

66. The system ofclaim 60, wherein the safe nominal operating range is between about 114V and about 126V and the user target voltage band is between about 114V and about 120V.

67. The system ofclaim 60, wherein the safe nominal operating range is between about 114V and about 126V and the user target voltage band is between about 116V and about 121V.

68. The system ofclaim 60, wherein the safe nominal operating range is between about 111V and about 129V the user target voltage band is between about 111V and about 120V.

69. The system ofclaim 60, wherein each sensor of the subset is located at a respective one of the plurality of user locations.

70. The system ofclaim 60, wherein at least one of the plurality of sensors is located on the distribution grid between the supply point and at least one of the user locations.

71. The system ofclaim 60, wherein the supply point is at a transformer at the substation.

72. The system ofclaim 60, wherein the plurality of sensors comprises a plurality of smart meters.

73. The system ofclaim 60, wherein the at least one sensor target voltage band comprises a plurality of sensor target voltage bands, each of the plurality of sensor target voltage bands corresponding to a respective sensor.

74. The system ofclaim 60, wherein the subset includes about twenty sensors on the distribution grid.

75. The system ofclaim 60, wherein the subset includes about ten sensors on a distribution circuit of the distribution grid.

76. The system ofclaim 75, wherein the distribution grid comprises two distribution circuits providing electric power to about 6400 user locations.

77. The electric power and control system ofclaim 1, wherein the electric power control system is a voltage control and energy conservation system, the electric power grid is an electric power transmission and distribution grid, and the plurality of consumption locations are a plurality of user locations;

wherein the at least one component of the supplied electric power is voltage;

wherein the controller is a voltage controller configured to generate an energy delivery parameter based on the measurement data received from the subset of the plurality of sensors;

wherein the adjusting device is a voltage adjusting device configured to adjust a voltage of the electric power supplied at the supply point based on the energy delivery parameter; and

wherein the energy delivery parameter is generated such that the voltage remains within a target voltage band.

78. The system ofclaim 77, wherein the subset of sensors comprises the bellwether sensors of the plurality of sensors that have the lowest sensed voltage.

79. The system ofclaim 77, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors.

80. The system ofclaim 79, wherein the subset includes about twenty sensors on the electric power grid.

81. The system ofclaim 79, wherein the subset includes about ten sensors on a distribution circuit of the electric power grid.

82. The system ofclaim 81, wherein the electric power grid comprises two distribution circuits providing electric power to about 6400 user locations.

83. The system ofclaim 77, wherein the voltage adjusting device comprises a load tap change transformer that adjusts the voltage of the electric power supplied at the supply point at a substation level based on a load tap change coefficient.

84. The system ofclaim 77, wherein the voltage adjusting device comprises a voltage regulator that adjusts the voltage of the electric power supplied at the supply point based on the energy delivery parameter.

85. The system ofclaim 84, wherein the voltage regulator comprises a circuit regulator that adjusts the voltage of the electric power supplied at the supply point at a line regulator level based on the energy delivery parameter.

86. The system ofclaim 77, wherein the energy delivery parameter is generated such that the voltage at each user location remains within a user target voltage band, the user target voltage band being a lower band of a safe nominal operating range.

87. The system ofclaim 86, wherein the safe nominal operating range is between about 114V and about 126V and the user target voltage band is between about 114V and about 120V.

88. The system ofclaim 77, wherein the sensors of the subset are selected based on predetermined criteria.

89. The system ofclaim 88, wherein the predetermined criteria includes historical sensor data.

90. The system ofclaim 77, wherein the voltage controller receives measurement data from each sensor at time intervals having a predetermined length.

91. The system ofclaim 77, wherein the voltage controller receives measurement data from each sensor of the subset at time intervals having a predetermined length.

92. The system ofclaim 91, wherein the time intervals each have a length of about five seconds to about fifteen minutes.

93. The system ofclaim 77, wherein the voltage controller receives measurement data from a sensor in response to a request by the controller.

94. The system ofclaim 77, wherein the voltage controller receives measurement data from a sensor when a predetermined event is detected.

95. The system ofclaim 77, wherein at least one other sensor of the plurality of sensors that is not included in the subset is further configured to send a respective reporting signal to the controller when the voltage sensed by the sensor is determined to be outside of a respective sensor target voltage band.

96. The system ofclaim 77, wherein the sensors of the subset are selected based on predetermined criteria, the subset of sensors includes the bellwether sensors of the plurality of sensors that have the lowest sensed voltage, and the selection includes the initial selection.

97. A method for controlling electrical power supplied to a plurality of distribution locations located at or between a supply point and at least one consumption location, each of the plurality of distribution locations including at least one sensor sensing at least one component of the supplied electric power received by the sensor at the respective distribution location and generating measurement data based on the sensed component, the method comprising:

receiving measurement data from a subset of the plurality of sensors, wherein the subset includes more than one and fewer than all of the plurality of sensors receiving the supplied electric power;

adding to the subset at least one other sensor in response to receiving a signal indicating that the component of the suppled electric power sensed by the at least one other sensor is outside a predetermined band, and

adjusting a component of the electric power supplied at the supply point based on the measurement data received from the subset of the plurality of sensors.

98. The method ofclaim 97, wherein the subset of sensors comprises the bellwether sensors of the plurality of sensors that have the lowest sensed measured component of electric power.

99. The method ofclaim 97, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors.

100. The method ofclaim 97, wherein the subset includes more than one and substantially fewer than all of the plurality of sensors receiving the supplied electric power.

101. The method ofclaim 97, further comprising the steps of:

receiving measurement data from a subset of the plurality of sensors at each of a plurality of time intervals haying a predetermined length; and

adjusting a component of the supplied power at the supply point based on a comparison of the measurement data received from the subset to at least one controller target component band.

102. The method ofclaim 101, wherein the time intervals have a length of about five seconds to about fifteen minutes.

103. The method ofclaim 97, wherein the sensors of the subset are selected based on predetermined criteria.

104. The method ofclaim 97, wherein the predetermined criteria includes historical sensor data.

105. The method ofclaim 97, wherein at least one other sensor of the plurality of sensors that is not included in the subset is further configured to send a respective reporting signal to the controller when the voltage sensed by the sensor is determined to be outside of a respective sensor target voltage band.

106. The method ofclaim 97, wherein the sensors of the subset are selected based on predetermined criteria, the subset of sensors includes the bellwether sensors of the plurality of sensors that have the lowest sensed voltage, and the selection includes the initial selection.

107. The method ofclaim 97, wherein the at least one consumption location is at least one user location, and the at least one component of the supplied electric power is voltage;

wherein adjusting a component of the electric power is adjusting a voltage at the supply point based on a comparison of the measurement data received from the subset to at least one target voltage band, the target voltage band being a lower band of a nominal operating range.

108. The method ofclaim 97, the method further comprising:

wherein the at least one consumption location is at least one user location, and the at least one component of the supplied electric power is voltage;

wherein adjusting a component of the electric power is adjusting a voltage at the supply point based on a comparison of the measurement data received from the subset to at least one controller target voltage band;

adjusting the sensors included in the subset based on the voltage sensed at at least one of the plurality of sensors.

109. The method ofclaim 97, the method further comprising:

wherein the at least one consumption location is at least one user location, and the at least one component of the supplied electric power is a voltage;

generating an energy delivery parameter based on the measurement data received from the subset of the plurality of sensors, and receiving measurement data from each sensor of the subset at time intervals having a predetermined length of from about five minutes to about fifteen minutes; and

adjusting a voltage of the electric power supplied at the supply point based on the energy delivery parameter, wherein the voltage adjusting device includes a load tap change transformer that adjusts the set-point voltage of the electric power supplied at the supply point at a substation level.

110. The method ofclaim 109, wherein an operator controls a controller in generating the energy delivery parameter and in adding to the subset.

111. The method ofclaim 97, the method further comprising:

wherein the at least one consumption location is at least one user location, and the at least one component of the supplied electric power is voltage;

generating an energy delivery parameter based on the measurement data received from the subset of the plurality of sensors, and, in response to operator control, adding to the subset the at least one other sensor based on the voltage sensed by the at least one other sensor being outside a predetermined voltage band.

112. The method ofclaim 97, the method further comprising:

wherein the at least one consumption location is at least one user location, and the at least one component of the supplied electric power is voltage;

generating an energy delivery parameter based on the measurement data received from the subset of the plurality of sensors, the measurement data being averaged over a predetermined period of time, receiving measurement data from each sensor of the subset at sensing time intervals having a predetermined length, and selecting the sensors for the subset based on predetermined criteria.

113. The method ofclaim 112, wherein the measurement data is averaged by at least one of a voltage controller, a collector or the sensors.

114. The method ofclaim 112, wherein the sensing time intervals have a predetermined length of from about five minutes to about fifteen minutes.

115. The method ofclaim 112, wherein the predetermined period of time is about one hour.

116. The method ofclaim 112, wherein the measurement data of an individual sensor is averaged together.

117. The method ofclaim 112, herein the measurement data of more than one sensor is averaged together.

118. The method ofclaim 112, wherein the selection includes the initial selection.

119. The method ofclaim 112, wherein the selection includes selections subsequent to an initial selection, the subsequent selections made at a predetermined selection time interval.

120. The method ofclaim 119, wherein the predetermined selection time interval is about twenty-four hours.

121. The method ofclaim 112, wherein the predetermined criteria includes the lowest sensed voltage averaged over the predetermined period of time and the lowest average voltage over the selection time interval.

122. The method ofclaim 112, wherein the subset of sensors includes the sensors of the plurality of sensors that have the lowest sensed voltage.

123. The method ofclaim 112, wherein the subset is selected in response to operator control.

124. The method ofclaim 112, further comprising adjusting a component of the electric power supplied at the supply point based on the energy delivery parameter.

125. The method ofclaim 124, wherein the energy delivery parameter is generated such that the voltage remains within a target voltage band, the target voltage band being a lower band of a nominal operating range.

126. The method ofclaim 125, wherein the target voltage band is a lower band of a nominal operating range.

127. The method ofclaim 112, wherein the predetermined criteria includes historical sensor data.

128. The method ofclaim 97, the method further comprising:

wherein the at least one consumption location is at least one user location, and the at least one component of the supplied electric power is voltage;

wherein the subset includes more than one but substantially fewer than all of the plurality of sensors;

wherein adjusting a component of the electric power is adjusting a voltage at the supply point based on a comparison of the measurement data received from the subset to at least one controller target voltage band, wherein voltage at the supply point is adjusted such that a voltage at each user location remains within a user target voltage band, the user target voltage band being a lower band of a safe nominal operating range; and

receiving a reporting signal indicating that a voltage that is sensed by another sensor that is not part of the subset is outside of a respective sensor target component band.

129. The method ofclaim 128, wherein the subset of sensors comprises the sensors of the plurality of sensors that have the lowest sensed voltages.

130. The method ofclaim 128, wherein the act of adjusting a voltage at the supply point further comprises determining an average voltage by averaging the data received from the subset and adjusting the voltage at the supply point based on the determined average voltage.

131. The method ofclaim 130, wherein the act of adjusting a voltage at the supply point further comprises adjusting the voltage at the supply point when one of the voltage at a user location or the determined average voltage is below a predetermined minimum voltage value, the predetermined minimum voltage value being based on the safe nominal operating range.

132. The method ofclaim 128, wherein the safe nominal operating range is between about 114V and about 126V and the user target voltage band is between about 114V and about 120V.

133. The method ofclaim 128, wherein the safe nominal operating range is between about 114V and about 126V and the user target voltage band is between about 116V and about 121V.

134. The method ofclaim 128, wherein the safe nominal operating range is between about 111V and about 129V the user target voltage band is between about 111V and about 120V.

135. A controller for an energy conservation system for an electric power transmission and distribution grid configured to supply electric power from a supply point to a plurality of user locations, the controller comprising:

at least one processor configured to:

receive measurement data that is based on a measured component of electric power from a subset of a plurality of sensors, wherein the plurality of sensors are each sensing at least one component of the electric power, generating measurement data, and are located at respective distribution locations on the distribution grid at or between the supply point and at least one of the plurality of user locations, and wherein the subset includes more than one and substantially fewer than all of the plurality of sensors

add to the subset at least one other sensor in response to receiving a signal indicating that the component of the suppled electric power sensed by the at least one other sensor is outside a predetermined band;

compare a controller target band to the measurement data received from the sensors in the subset: and

adjust an adjusting device configured to adjust the electric power supplied at the supply point based on the measurement data received from the subset of the plurality of sensors.

136. The controller ofclaim 135, wherein the subset of sensors comprises the sensors of the plurality of sensors that have the lowest sensed measured component of electric power.

137. The controller ofclaim 135, wherein the controller is configured to receive a signal indicating that the measured component of electric power sensed by at least one other sensor of the plurality of sensors is outside of a sensor target component band, wherein the predetermined band is a sensor target component band, and wherein the controller is further configured to de-select at least one of the sensors in the subset when adding the at least one other sensor to the subset.

138. The controller ofclaim 137, wherein the controller is configured to maintain a set number of sensors in the subset.

139. The controller ofclaim 135, wherein the controller is further configured to adjust the adjusting device such that a voltage at each user location remains within a user target voltage band, the user target voltage band being a lower band of a sate nominal operating range.

140. The controller ofclaim 135, wherein the sale nominal operating range is between about 114V and about 126V and the user target voltage band is between about 114V and about 120V.

141. The controller ofclaim 135, wherein the safe nominal operating range is between about 114V and about 126V and the user target voltage band is between about 116V and about 121V.

142. The controller ofclaim 135, wherein the safe nominal operating range is between about 111V and about 129V the user target voltage band is between about 111V and about 120V.

143. The system ofclaim 1, wherein the controller is configured to:

store historical component data that includes at least one of aggregated energy component data at a substation level, electric power component data at a substation level, and weather data;

determine energy usage at each of the plurality of sensors;

compare the historical component data to the determined energy usage; and

determine energy savings attributable to the system based on the results of the comparison of the historical component data to the determined energy usage.

144. The electric power and control system ofclaim 17, wherein the electric power control system is a voltage control and energy conservation system, the electric power grid is an electric power transmission and distribution grid, and the plurality of consumption locations are a plurality of user locations, the system comprising:

wherein the at least one component of the supplied electric power voltage;

wherein the controller is a voltage controller, and wherein the voltage controller receives measurement data from each sensor of the subset at time intervals having a predetermined length of from about five minutes to about fifteen minutes, wherein the component of the suppled electric power sensed by the at least one other sensor is voltage and the predetermined band is a predetermined voltage band; and

wherein the adjusting devices is a voltage adjusting device configured to adjust a voltage of the electric power supplied at the supply point based on the measurement data, wherein the voltage adjusting device includes a load tap change transformer that adjusts the set-point voltage of the electric power supplied at the supply point at a substation level.

145. The system ofclaim 144, wherein an operator controls the controller in adjusting the adjusting device and in adding to the subset.

146. The electric power and control system ofclaim 1, wherein the electric power control system is a voltage control and energy conservation system, the electric power grid is an electric power transmission and distribution grid, and the plurality of consumption locations are a plurality of user locations;

wherein the at least one component of the supplied electric power is voltage;

wherein the controller is a voltage controller, and wherein the component of the suppled electric power sensed by the at least one other sensor is voltage and the predetermined band is a predetermined voltage band.

147. The electric power and control system ofclaim 1, wherein the electric power control system is a voltage control and energy conservation system, the electric power grid is an electric power transmission and distribution grid, and the plurality of consumption locations are a plurality of user locations;

wherein the at least one component of the supplied electric power is voltage;

wherein the controller is a voltage controller, wherein the measurement data is averaged over a predetermined period of time, and wherein the voltage controller receives measurement data from each sensor of the subset at sensing time intervals having a predetermined length, wherein the controller is further configured to select the sensors for the subset based on predetermined criteria.

148. The system ofclaim 147, wherein the measurement data is averaged by at least one of the controller, a collector or the sensors.

149. The system ofclaim 147, wherein the sensing time intervals have a predetermined length of from about five minutes to about fifteen minutes.

150. The system ofclaim 147, wherein the predetermined period of time is about one hour.

151. The system ofclaim 147, wherein the measurement data of an individual sensor is averaged together.

152. The system ofclaim 147, wherein the measurement data of more than one sensor is averaged together.

153. The system ofclaim 147, wherein the selection includes the initial selection.

154. The system ofclaim 147, wherein the selection includes selections subsequent to an initial selection, the subsequent selections made at a predetermined selection time interval.

155. The system ofclaim 154, wherein the predetermined selection time interval is about twenty-four hours.

156. The system ofclaim 154, wherein the predetermined criteria includes the lowest sensed voltage averaged over the predetermined period of time and the lowest average voltage over the selection time interval.

157. The system ofclaim 147, wherein the subset of sensors includes the sensors of the plurality of sensors that have the lowest sensed voltage.

158. The system ofclaim 147, wherein the controller is further configured to select the subset in response to operator control.

159. The system ofclaim 1, wherein the adjusting device is adjusted such that the voltage remains within a target voltage band, the target voltage band being a lower band of a nominal operating range.

160. The system ofclaim 159, wherein the target voltage band is a lower band of a nominal operating range.

161. The system ofclaim 147, wherein the predetermined criteria includes historical sensor data.

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