Abstract:
An energy management system utilizing a home automation aggregation controller provides a retail energy supplier with means to manage electric energy supply characteristics.

Description:
PRIORITY CLAIM 
       [0001]    This application claims priority to U.S. Provisional Patent Application No. 61/761,300 filed Feb. 6, 2013 and which is incorporated herein in its entirety and for all purposes. 
     
    
     BACKGROUND OF THE INVENTION 
       [0002]    1. Field of the Invention 
         [0003]    The invention relates to a process. In particular, the invention includes a method for managing the supply of electric power. 
         [0004]    2. Discussion of the Related Art 
         [0005]    Electric power is supplied to residential, commercial, and industrial customers. Little thought or infrastructure has been devoted to automated means for collecting data and using that data individually and corporately to manage the energy supply to meet goals set by consumers and their energy suppliers. 
       SUMMARY OF THE INVENTION 
       [0006]    The present invention provides a method of operating an electric power energy management business. In various embodiments, the present invention provides for more effective management of electric supplies. 
         [0007]    In an embodiment, management functions coordinate and optimize customer loads and load reduction actions, with external influences such as weather, electricity market prices and system wide loads on the grid to reduce costs, peak loads, energy consumption and carbon production. For example, aggregators can take advantage of unique value propositions for utilities and customers when these factors are optimized to benefit from their interdependence. 
         [0008]    Notably, while some benefits of the present invention depend upon markets having de-regulated electricity prices, embodiments of the invention remain useful for managing energy consumption and carbon reduction. 
         [0009]    Embodiments of the invention provide for peak load management including peak load reduction. For example, peak load reduction benefits utilities and Independent System Operators (“ISO”) where it enables improved asset utilization, reduced congestion on transmission and distribution wires, and reduced loads when generators are constrained. 
         [0010]    Embodiments provide consumers benefits such as cost savings through energy conservation and reduced procurement costs. Procurement cost reductions include one or more of constructing flatter load profiles enabling participation in real time electricity markets and providing consumers with a menu of ancillary services. 
         [0011]    Aggregation service providers package and or manage electric power loads of many consumers. They offer programs such as Community Choice Aggregation programs and subscription programs that purchase power for participating consumers. In various embodiments, aggregators fully or partially control customer loads and combine customers into groups for managing the combined load profiles of these groups. Flatten load profiles, that is load profiles that have nearly the same load over the course of every hour in the day, are more desirable because, inter alia, such profiles enhance utilization of electric power infrastructure resources. Typically, aggregators can reduce electric power costs by constructing a load profile from many consumers that tends to flatten the summed load. 
         [0012]    When purchasing power for a group of customers, aggregators may choose to purchase all or some of the power in real time electricity markets where prices change as often as every five minutes, or in markets where the prices change hourly, for example, but are a determined the day before (“day-ahead markets”). In various embodiments, kilowatt hours purchased in real time electricity markets depends at least partially on the aggregator&#39;s ability to control loads and in particular to reduce loads when real time prices are high. Generally power the average price over power over the course of a year is about 20 to 25% less than the flat rate prices of power offered by utilities and energy service providers, but real time prices can be higher than utility prices a few hundred hours of the year. 
     
    
     
       BRIEF DESCRIPTION OF THE DRAWINGS 
         [0013]    The present invention is described with reference to the accompanying figures. These figures, incorporated herein and forming part of the specification, illustrate the present invention and, together with the description, further serve to explain the principles of the invention and to enable a person skilled in the relevant art to make and use the invention. 
           [0014]      FIG. 1  shows a block diagram of a prior art electric power delivery system. 
           [0015]      FIG. 2  shows a block diagram of an energy management system in accordance with the present invention. 
           [0016]      FIG. 3  shows a block diagram of an energy management system in accordance with the present invention. 
           [0017]      FIG. 4  shows a block diagram of an energy management system in accordance with the present invention. 
           [0018]      FIG. 5  shows a block diagram of an energy management system in accordance with the present invention. 
       
    
    
     DETAILED DESCRIPTION OF THE PREFERRED EMBODIMENTS 
       [0019]    The disclosure provided in the following pages describes examples of some embodiments of the invention. The designs, figures, and descriptions are non-limiting examples of certain embodiments of the invention. For example, other embodiments of the disclosed device may or may not include the features described herein. Moreover, disclosed advantages and benefits may apply to only certain embodiments of the invention and should not be used to limit the disclosed inventions. 
         [0020]      FIG. 1  shows a block diagram of a prior art electric power delivery system  100 . Here, electric service processes  102  serve customer sites  110  while generation management processes  112  balance generation  108  with demand. 
         [0021]    In various embodiments, generation management  112  is carried out by an electric service company such as an electric utility company and in various embodiments generation management is carried out by an external entity such as an Independent System Operator (“ISO”) or Regional Transmission Authority (“RTA”). Where an external generation management entity is involved, some embodiments provide a plurality of integrated electric service entities (“utilities”) or electric generating entities within a generation manager&#39;s control. 
         [0022]    Electric service processes  102  include local utility processes  104 , transmission process  106 , and generation process  108 . Local utility processes encompass electric distribution  130  and collection processes  132  such as customer invoicing and payment processes. 
         [0023]    Distribution processes interface with customer sites for supplying energy to customer sites. These distribution processes utilize a physical interface including distribution equipment such as distribution power lines  114 . Collection processes interface with customer sites and/or customer site payors to receive compensation for services provided. 
         [0024]    Collection processes utilize meter reading (physically or remotely read)  116  to determine consumption energy charges. Collection processes also include preparing invoices and receiving payments (information and funds transfers)  118 . 
         [0025]    Meter reading  116  includes remote reading of meters and manual reading of meters where necessary. Collection processes  132  interface with customer sites  110  when invoices are provided to and payments are received from customer sites and/or customer site payors (information and funds transfer interfaces)  118 . 
         [0026]    Local utility processes  104  are enabled by transmission processes  106  which are in turn enabled by generation processes  108 . The transmission process is coupled to local utility processes via a transmission/local utility physical interface  134 . This physical interface typically includes high voltage electric power transmission lines that interconnect with lower voltage distribution equipment via substations including step-down transformer(s). 
         [0027]    Generation processes  108  supply power to enable the transmission processes  106 . The generation processes are coupled to the transmission processes via a generation/transmission physical interface  136 . This physical interface typically includes medium voltage electric power lines interconnecting with high voltage electric power transmission lines via step-up transformer(s). 
         [0028]      FIG. 2  shows an energy management system in accordance with the present invention  200 . The energy management system includes an ancillary services manager  214 , electric utility functions  102 , a customer site and customer site payor  110  and an entity balancing production and demand (“balance manager”)  206 . 
         [0029]    Ancillary services of the ancillary services manager  214  include retail energy supplier/aggregation (“RES”) services  202  and automation aggregation controller (“AAC”) services  204 . A data transfer medium enables the RES and the AAC to exchange data. 
         [0030]    An entity balancing production &amp; demand (“balance manager”)  206  exchanges data  220  with the electric utility functions  102  and with an ancillary services manager  214 . The ancillary services manager also exchanges data and commands with the customer site  210  and in some embodiments with a customer site payor  110  (as shown). 
         [0031]      FIG. 3  shows an embodiment of the energy management system of the present invention  300 . The system includes a RES  202 , an AAC  204 , customer sites  304 , a selected group of customer sites  302 , an electric utility entity performing one or more electric utility functions  102 , and a balance manager  206 . 
         [0032]    The RES  202  and the AAC  204  exchange data  208 . Customer sites  302  exchange data and commands  308  with the AAC  204 , receive energy  114  from the electric utility function  102 , and make payments  118  to the electric utility function. The balance manager  206  exchanges data  220 ,  212  with each of the electric utility function and the AAC  102 ,  204 . The electric utility function also exchanges data  220  with the balance manager  206 . In various embodiments, there is a selected group of customer sites  304  that exchanges data and commands  306  with the AAC. 
         [0033]    As discussed above, the AAC  204  exchanges data and commends with the RES  202 , customer sites, a selected group of customer sites  304 , and with the balance manager  206 . 
         [0034]    Main functions of the AAC include data collection, data analysis, and responding to energy management choices. 
         [0035]    AAC data collection includes collecting real time customer site data and maintaining that historical site data or a subset of it. From the customer site data, the AAC builds and then updates site electric load models. These models are used to forecast demand. 
         [0036]    Knowledge of site electricity demand is used in various embodiments to gather customer sites into groups that provide an aggregate electricity demand that is favorable when electricity pricing is considered. For example, customer sites can be grouped to levelize the load such that load variation with respect to average load is reduced. The electricity demand or load profile for each group of sites is forecast by summing the individual site forecasts, a calculation performed as needed, for example on fixed or event driven intervals or times. 
         [0037]    Estimates of the curtailment potential for each site  302  and for each group of sites  304  are made by the AAC  204 . Curtailment potential refers to discretionary electric loads at one or more customer sites that can be remotely managed to reduce the site(s) electricity demand. In some embodiments, these estimates take into account a customer&#39;s choice to participate in or forgo participation in a load curtailment program. The AAC  204  estimates curtailment potential for each site  302  and for each group of sites  304 . 
         [0038]    With forecasted electric load profiles for customer sites  302  and for groups of customer sites  304 , the AAC can anticipate individual and aggregate loads. Load profile anticipation provides an opportunity to manage particular loads and aggregate loads such that these loads come within favorable terms of electric services contracts such as electric supply contracts. 
         [0039]    Participation in demand response events is enabled by possession of curtailment potential estimates for each site  302  and each group of sites  304 . The AAC  204  is capable of participating in demand response events whether they be externally noticed, such as by the balance manager  206  or the electric utility  102 , or internally noticed, such as by the AAC or the RES  202 . In a similar fashion, the AAC can respond to electricity conservation opportunities. And, where there is a take or pay electricity supply contract, the AAC can make excess power available for sale or end energy saving programs such as load curtailment. 
         [0040]    As discussed above, the customer sites  302  exchange data with the AAC  204 . Main functions of the customer sites include sensing site data and receiving site instructions. 
         [0041]    Sensing site data includes several measurements. Electricity usage is measured and in various embodiments the status of selected loads (e.g., on/off) is monitored. In addition, occupancy is sensed and temperature(s) including indoor air temperature are measured. 
         [0042]    Customer site occupants and/or customer site payors provide instructions relating to the customer sites. Instructions pertaining to preferences are given. In addition, demand response and conservation opportunities can be opted into or out of. 
         [0043]    As discussed above, selected sites are grouped  304  for purposes such as load leveling through aggregation. The AAC exchanges data and commands  306  with the customer sites within the group. In various embodiments, all of the sites within the group receive common commands. And, in some embodiments particular sites within the group receive individualized commands. 
         [0044]    Load curtailment instructions are typically particularized as are commands dispatching electricity sources such as motor-generator sets. Instructions received at the sites cause operation of direct controls such as lighting controls. Instructions received at the sites also operate indirect controls such as programmable thermostats. Direct Instructions control devices such as site lighting. 
         [0045]      FIG. 4  shows an embodiment of the energy management system of the present invention  400 . The system includes a RES  202 , an AAC  204 , customer sitepayors  402 , an electric utility or entity performing one or more electric utility functions  102 , customer sites  302 , and a balance manager  206 . 
         [0046]    As shown, the RES  202  exchanges data with the AAC  204 . AAC data including one or more of historical power usage, weather forecasts, and load models provide the RES with a basis for determining power purchase contract parameters including one or more of average load, time of day load, peak loads, and duration of peak loads. Taking these parameters into account, the RES enters into electric power supply contracts with power seller(s) such as bulk power seller(s). 
         [0047]    Profit sharing is also determined by the RES. In an embodiment, the electric utility  102  collects 118 payments (x) from customer site payors  402 . The utility retains a portion of the payment (y) and sends  410  the balance (x-y) to the RES  202 . The RES determines its share (z) and sends  412  the balance (x-y-z) to the customer site payor. In other embodiments, the rebate is deducted from an electric services invoice the utility sends the customer site payor avoiding an ex post facto rebate. In various embodiments, customer site payors opt in and/or out of one or more of demand response events, energy conservation opportunities, and profit sharing. 
         [0048]    In various embodiments, the RES  202  optimizes electric supply and selects strategy and preferences. For example, while holding long term supply contracts, the RES may contract to sell back take or pay blocks of power on certain days as a part of daily tactics and strategy. In an embodiment, such a transaction takes place when the RES holds surplus power. Support for various of these RES functions includes the availability of forecasts such as AAC forecasts taking into account load that must be served with real-time purchases and the cost of such purchases. 
         [0049]      FIG. 5  shows an embodiment of the energy management system of the present invention  500 . The system includes a RES  202 , an AAC  204 , customer sites  302 , an electric utility  102 , a weather forecast data source  502 , and a balance manager  206 . 
         [0050]    In addition, some embodiments include a data server  510  supplying data directly to customers  512  and/or supplying data to customers  516  via an application such as an IPHONE® application, another mobile device application, or via any suitable internet connected device. 
         [0051]    An addendum to this specification provides additional disclosure of the present invention. In particular, text and figures describe additional embodiments of the present invention together with descriptions of algorithms incorporated in various embodiments of the invention. The Addendum forms a part of this specification and is included herewith. 
         [0052]    While various embodiments of the present invention have been described above, it should be understood that they have been presented by way of example only, and not limitation. It will be apparent to those skilled in the art that various changes in the form and details can be made without departing from the spirit and scope of the invention. As such, the breadth and scope of the present invention should not be limited by the above-described exemplary embodiments, but should be defined only in accordance with the following claims and equivalents thereof.