System and method for estimating and providing dispatchable operating reserve energy capacity through use of active load management

Description

BACKGROUND OF THE INVENTION
1. Field of the Invention

The present invention relates generally to the field of electric power supply and generation systems and, more particularly, to a system and method for estimating and/or providing dispatchable operating reserve energy capacity for an electric utility using active load management so that the reserve capacity may be made available to the utility or to the general power market (e.g., via a national grid).

2. Description of Related Art

Energy demand within a utility's service area varies constantly. Such variation in demand can cause undesired fluctuations in line frequency if not timely met. To meet the varying demand, a utility must adjust its supply or capacity (e.g., increase capacity when demand increases and decrease supply when demand decreases). However, because power cannot be economically stored, a utility must regularly either bring new capacity on-line or take existing capacity off-line in an effort to meet demand and maintain frequency. Bringing new capacity online involves using a utility's reserve power, typically called “operating reserve.” A table illustrating a utility's typical energy capacity is shown in FIG. 1. As shown, operating reserve typically includes three types of power: so-called “regulating reserve,” “spinning reserve,” and “non-spinning reserve” or “supplemental reserve.” The various types of operating reserve are discussed in more detail below.

Normal fluctuations in demand, which do not typically affect line frequency, are responded to or accommodated through certain activities, such as by increasing or decreasing an existing generator's output or by adding new generating capacity. Such accommodation is generally referred to as “economic dispatch.” A type of power referred to as “contingency reserve” is additional generating capacity that is available for use as economic dispatch to meet changing (increasing) demand. Contingency reserve consists of two of the types of operating reserve, namely, spinning reserve and non-spinning reserve. Therefore, operating reserve generally consists of regulating reserve and contingency reserve.

As shown in FIG. 1, spinning reserve is additional generating capacity that is already online (e.g., connected to the power system) and, thus, is immediately available or is available within a short period of time after a determined need (e.g., within ten (10) to fifteen (15) minutes, as defined by the applicable North American Electric Reliability Corporation (NERC) regulation). More particularly, in order for contingency reserve to be classified as “spinning reserve,” the reserve power capacity must meet the following criteria:

a) be connected to the grid;

b) be measurable and verifiable; and

c) be capable of fully responding to load typically within 10-15 minutes of being dispatched by a utility, where the time-to-dispatch requirements of the spinning reserve are generally governed by a grid system operator or other regulatory body, such as NERC.

Non-spinning reserve (also called supplemental reserve) is additional generating capacity that is not online, but is required to respond within the same time period as spinning reserve. Typically, when additional power is needed for use as economic dispatch, a power utility will make use of its spinning reserve before using its non-spinning reserve because (a) the generation methods used to produce spinning reserve capacity typically tends to be cheaper than the methods, such as one-way traditional demand response, used to produce non-spinning reserve or (b) the consumer impact to produce non-spinning reserve is generally less desirable than the options used to produce spinning reserve due to other considerations, such as environmental concerns. For example, spinning reserve may be produced by increasing the torque of rotors for turbines that are already connected to the utility's power grid or by using fuel cells connected to the utility's power grid; whereas, non-spinning reserve may be produced from simply turning off resistive and inductive loads such as heating/cooling systems attached to consumer locations. However, making use of either spinning reserve or non-spinning reserve results in additional costs to the utility because of the costs of fuel, incentives paid to consumers for traditional demand response, maintenance, and so forth.

If demand changes so abruptly and quantifiably as to cause a substantial fluctuation in line frequency within the utility's electric grid, the utility must respond to and correct for the change in line frequency. To do so, utilities typically employ an Automatic Generation Control (AGC) process or subsystem to control the utility's regulating reserve. To determine whether a substantial change in demand has occurred, each utility monitors its Area Control Error (ACE). A utility's ACE is equal to the difference in the scheduled and actual power flows in the utility grid's tie lines plus the difference in the actual and scheduled frequency of the supplied power multiplied by a constant determined from the utility's frequency bias setting. Thus, ACE can be written generally as follows:

ACE=(NI.sub.A-NI.sub.S)+(−10B.sub.1)(F.sub.A-F.sub.S), [Equation 1]

where:

NI.sub.A is the sum of actual power flows on all tie lines,

Ni.sub.S is the sum of scheduled flows on all tie lines,

B.sub.1 is the frequency bias setting for the utility,

F.sub.A is the actual line frequency, and

F.sub.S is the scheduled line frequency (typically 60 Hz).

In view of the foregoing ACE equation, the amount of loading relative to capacity on the tie lines causes the quantity (NI.sub.A-NI.sub.S) to be either positive or negative. When demand is greater than supply or capacity (i.e., the utility is under-generating or under-supplying), the quantity (NI.sub.A-NI.sub.S) is negative, which typically causes ACE to be negative. On the other hand, when demand is less than supply, the quantity (NI.sub.A-NI.sub.S) is positive (i.e., the utility is over-generating or over-supplying), which typically causes ACE to be positive. The amount of demand (e.g., load) or capacity directly affects the quantity (NI.sub.A-NI.sub.S); thus, ACE is a measure of generation capacity relative to load. Typically, a utility attempts to maintain its ACE very close zero using AGC processes.

If ACE is not maintained close to zero, line frequency can change and cause problems for power consuming devices attached to the electric utility's grid. Ideally, the total amount of power supplied to the utility tie lines must equal the total amount of power consumed through loads (power consuming devices) and transmission line losses at any instant of time. However, in actual power system operations, the total mechanical power supplied by the utility's generators is seldom exactly equal to the total electric power consumed by the loads plus the transmission line losses. When the power supplied and power consumed are not equal, the system either accelerates (e.g., if there is too much power in to the generators) causing the generators to spin faster and hence to increase the line frequency or decelerates (e.g., if there is not enough power into the generators) causing the line frequency to decrease. Thus, variation in line frequency can occur due to excess supply, as well as due to excess demand.

To respond to fluctuations in line frequency using AGC, a utility typically utilizes “regulating reserve,” which is one type of operating reserve as illustrated in FIG. 1. Regulating reserve is used as needed to maintain constant line frequency. Therefore, regulating reserve must be available almost immediately when needed (e.g., in as little as a few seconds to less than about five (5) minutes). Governors are typically incorporated into a utility's generation system to respond to minute-by-minute changes in load by increasing or decreasing the output of individual generators and, thereby, engaging or disengaging, as applicable, the utility's regulating reserve.

The Federal Energy Reliability Commission (FERC) and NERC have proposed the concept of Demand Side Management (DSM) as an additional approach to account for changes in demand. DSM is a method in which a power utility carries out actions to reduce demand during peak periods. Examples of DSM include encouraging energy conservation, modifying prices during peak periods, direct load control, and others.

Current approaches for using DSM to respond to increases in demand have included using one way load switches that interrupt loads, as well as statistics to approximate the average amount of projected load removed by DSM. A statistical approach is employed because of the utility's inability to measure the actual load removed from the grid as a result of a DSM load control event. In addition, current DSM approaches have been limited to use of a single power measuring meter among every one hundred (100) or more service points (e.g., residences and/or businesses). Accordingly, current DSM approaches are inadequate because they rely on statistical trends and sampling, rather than on empirical data, to make projections and measure actual load removal events.

More recently, FERC and NERC have introduced the concept of flexible load-shape programs as a component of DSM. These programs allow customers to make their preferences known to the utility concerning timing and reliability of DSM load control events. However, DSM approaches utilizing load-shaping programs do not meet all of the criteria for implementing regulating reserve or spinning reserve, such as being dispatchable within 15 minutes or less. Additionally, in order for a generating source to be considered dispatchable energy, it must be forecasted twenty-four (24) hours prior to being delivered to a utility. Current DSM approaches do not facilitate accurate forecasting twenty-four (24) hours in advance due to their heavy reliance on statistics.

Therefore, there is a need for utilities to be able to create operating reserve, especially regulating and/or spinning reserve, by using accurate forecasting and flexible load shaping techniques. There is a further need to involve the consumer in a two-way approach in which the consumer can make their energy consumption preferences known and the utility can make use of those preferences to respond to increased demand and maintain line frequency regulation.

BRIEF DESCRIPTION OF THE DRAWINGS

FIG. 1 is a table showing the base load power requirements and operating reserve available to an electric power utility.

FIG. 2 is a block diagram illustrating how an active load management system in accordance with the present invention provides additional operating (e.g., regulating, spinning and/or non-spinning) reserve to a power utility.

FIG. 3 is a block diagram of an exemplary IP-based, active load management system in accordance with one embodiment of the present invention.

FIG. 4 is a block diagram illustrating an exemplary active load director as shown in the power load management system of FIG. 3.

FIG. 5 is a block diagram illustrating generation of an exemplary sampling repository at the active load director of FIG. 4 or some other location in an electric utility.

FIG. 6 is a screen shot of an exemplary web browser interface through which a customer may designate his or her device performance and energy saving preferences for an environmentally-dependent, power consuming device in accordance with one embodiment of the present invention.

FIG. 7 is a screen shot of an exemplary web browser interface through which a customer may designate his or her device performance and energy saving preferences for an environmentally-independent, power consuming device in accordance with another embodiment of the present invention.

FIG. 8 is an operational flow diagram illustrating a method for empirically analyzing power usage of power consuming devices and populating a repository with data samples resulting from such power usage analysis, in accordance with an exemplary embodiment of the present invention.

FIG. 9 is an operational flow diagram illustrating a method for projecting energy usage for a power consuming device in accordance with an exemplary embodiment of the present invention.

FIG. 10 is an operational flow diagram illustrating a method for estimating power consumption behavior of a power consuming device in accordance with an exemplary embodiment of the present invention.

FIG. 11 is an operational flow diagram illustrating a method for projecting energy savings through power interruption to a power consuming device during a control event, in accordance with an exemplary embodiment of the present invention.

FIG. 12 is a graph that depicts a load profile of a utility during a projected time period, showing actual energy usage as well as projected energy usage determined with and without a control event, in accordance with an exemplary embodiment of the present invention.

FIG. 13 is a block diagram of a system for implementing a virtual electric utility in accordance with an exemplary embodiment of the present invention.

DETAILED DESCRIPTION OF EXEMPLARY EMBODIMENTS

Before describing in detail exemplary embodiments that are in accordance with the present invention, it should be observed that the embodiments reside primarily in combinations of apparatus components and processing steps related to actively monitoring and managing power loading at an individual service point (e.g., on an individual subscriber basis) and throughout a utility's service area, as well as determining available or dispatchable operating reserve power derived from projected power savings resulting from monitoring and management of power loading. Accordingly, the apparatus and method components have been represented where appropriate by conventional symbols in the drawings, showing only those specific details that are pertinent to understanding the embodiments of the present invention so as not to obscure the disclosure with details that will be readily apparent to those of ordinary skill in the art having the benefit of the description herein.

In this document, relational terms, such as “first” and “second,” “top” and “bottom,” and the like, may be used solely to distinguish one entity or element from another entity or element without necessarily requiring or implying any physical or logical relationship or order between such entities or elements. The terms “comprises,” “comprising,” and any other variation thereof are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements, but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. The term “plurality of” as used in connection with any object or action means two or more of such object or action. A claim element proceeded by the article “a” or “an” does not, without more constraints, preclude the existence of additional identical elements in the process, method, article, or apparatus that includes the element.

Additionally, the term “ZigBee” refers to any wireless communication protocol adopted by the Institute of Electronics & Electrical Engineers (IEEE) according to standard 802.15.4 or any successor standard(s), the term “Wi-Fi” refers to any communication protocol adopted by the IEEE under standard 802.11 or any successor standard(s), the term “WiMax” refers to any communication protocol adopted by the IEEE under standard 802.16 or any successor standard(s), and the term “Bluetooth” refers to any short-range communication protocol implementing IEEE standard 802.15.1 or any successor standard(s). Additionally or alternatively to WiMax, other communications protocols may be used, including but not limited to a “1 G” wireless protocol such as analog wireless transmission, first generation standards based (IEEE, ITU or other recognized world communications standard), a “2-G” standards based protocoal such as “EDGE or CDMA 2000 also known as 1×RTT”, a 3G based standard such as “High Speed Packet Access (HSPA) or Evolution for Data Only (EVDO), any accepted 4G standard such as “IEEE, ITU standards that include WiMax, Long Term Evolution “LTE” and its derivative standards, any Ethernet solution wireless or wired, or any proprietary wireless or power line carrier standards that communicate to a client device or any controllable device that sends and receives an IP based message.

The term “High Speed Packet Data Access (HSPA)” refers to any communication protocol adopted by the International Telecommunication Union (ITU) or another mobile telecommunications standards body referring to the evolution of the Global System for Mobile Communications (GSM) standard beyond its third generation Universal Mobile Telecommunications System (UMTS) protocols. The term “Long Term Evolution (LTE)” refers to any communication protocol adopted by the ITU or another mobile telecommunications standards body referring to the evolution of GSM-based networks to voice, video and data standards anticipated to be replacement protocols for HSPA. The term “Code Division Multiple Access (CDMA) Evolution Date-Optimized (EVDO) Revision A (CDMA EVDO Rev. A)” refers to the communication protocol adopted by the ITU under standard number TIA-856 Rev. A.

The terms “utility,” “electric utility,” “power utility,” and “electric power utility” refer to any entity or system that generates, distributes, and/or resells electrical power, including any market participant associated with an electric power grid, microgrid, etc., that purchases power from a power-generating entity and distributes the purchased power to end user customers, or that supplies electricity created either actually or virtually by alternative energy sources, such as solar power, wind power, load control, or otherwise, to power generation or distribution entities through the FERC electrical grid or otherwise, or that schedules the supply of energy or ancillary services, such as operating reserves. Therefore, as used herein and in the appended claims, an “electric utility” may be a power-generating entity, a power-distributing entity, a retail electric provider (REP), an independent system operator (ISO), an electrical grid operator, or any other market participant, such as any entity that performs the function of a load serving entity (LSE), a qualified scheduling entity (QSE), a resource entity (RE), or a transmission/distribution service provider (TDSP), as such entities and participants are understood by those of ordinary skill in the art in the electricity industry.

The terms “energy” and “power” are used interchangeably herein. The terms “operating reserve,” “spinning reserve,” “regulating reserve,” “non-spinning reserve,” “supplemental reserve,” and “contingency reserve” are conventional in the art and their uses and inter-relations are described in hereinabove. The term “environment” refers to general conditions, such as air temperature, humidity, barometric pressure, wind speed, rainfall quantity, water temperature, etc., at or proximate a service point or associated with a device (e.g., water temperature of water in a hot water heater or a swimming pool).

The term “device,” as used herein, means a power-consuming device, and there may generally be two different types of devices within a service point, namely, an environmentally-dependent device and an environmentally-independent device. An environmentally-dependent device is any power consuming device that turns on or off, or modifies its behavior, based on one or more sensors that detect characteristics, such as temperature, humidity, pressure, or various other characteristics, of an environment. An environmentally-dependent device may directly affect and/or be affected by the environment in which it operates. An environmentally-independent device is any power-consuming device that turns on or off, or modifies its behavior, without reliance upon inputs from any environmental sensors. Generally speaking, an environmentally-independent device does not directly affect, and is not typically affected by, the environment in which it operates, although, as one skilled in the art will readily recognize and appreciate, operation of an environmentally-independent device can indirectly affect, or occasionally be affected by, the environment. For example, as those skilled in the art readily understand, a refrigerator or other appliance generates heat during operation, thereby causing some heating of the ambient air proximate the device.

It will be appreciated that embodiments or components of the systems described herein may be comprised of one or more conventional processors and unique stored program instructions that control the one or more processors to implement, in conjunction with certain non-processor circuits, some, most, or all of the functions for determining an electric utility's available or dispatchable operating (e.g., regulating and spinning) reserve that is derived from projected power savings resulting from monitoring and management of loads in one or more active load management systems as described herein. The non-processor circuits may include, but are not limited to, radio receivers, radio transmitters, antennas, modems, signal drivers, clock circuits, power source circuits, relays, meters, memory, smart breakers, current sensors, and user input devices. As such, these functions may be interpreted as steps of a method to store and distribute information and control signals between devices in a power load management system. Alternatively, some or all functions could be implemented by a state machine that has no stored program instructions, or in one or more application specific integrated circuits (ASICs), in which each function or some combinations of functions are implemented as custom logic. Of course, a combination of the foregoing approaches could be used. Thus, methods and means for these functions have been described herein. Further, it is expected that one of ordinary skill in the art, notwithstanding possibly significant effort and many design choices motivated by, for example, available time, current technology, and economic considerations, when guided by the concepts and principles disclosed herein, will be readily capable of generating such software instructions, programs and integrated circuits (ICs), and appropriately arranging and functionally integrating such non-processor circuits, without undue experimentation.

Generally, the present invention encompasses a system and method for estimating operating reserve (e.g., spinning and/or regulating reserve) for a utility servicing one or more service points. In one embodiment, the utility or any market participant associated with the electric power grid, employs an active load management system (ALMS) to remotely determine, during at least one period of time, power consumed by at least one device located at the one or more service points and receiving power from the utility to produce power consumption data. The power consumption data is regularly stored and updated in a repository. The ALMS or a control component thereof, such as an active load director (ALD), determines an expected, future time period for a control event during which power is to be interrupted or reduced to one or more devices. Prior to commencement of the control event, the ALMS or its control component: (i) estimates power consumption behavior expected of the device(s) during the time period of the control event based at least on the stored power consumption data, (ii) determines projected energy savings resulting from the control event based at least on the estimated power consumption behavior of device(s), and determines operating (e.g., regulating and/or spinning) reserve based on the projected energy savings. The determined operating reserve may be made available to the current power utility or to the power market through the existing (e.g., Federal Energy Regulatory Commission) power grid. In one embodiment, the ALD populates an internal repository (e.g., database, matrix, or other storage medium) with measurement data indicating how individual devices within individual service points consume power or otherwise behave under normal operation and during control events. The power consumption data is updated through regular (e.g., periodic or otherwise) sampling of device operating conditions (e.g., current draw, duty cycle, operating voltage, etc.). When an ALD is first installed in an ALMS for an electric utility power grid, there is little data with which to create regulating and spinning reserve forecasts. However, over time, more and more data samples are used to improve the quality of the data in the repository. This repository is used to project both energy usage and energy savings. These projections can be aggregated for an entire service point, a group of service points, or the entire utility.

Furthermore, based upon the reduction in consumed power, the systems and methods of the present invention provide for generating at the control center a power supply value (PSV) corresponding to the reduction in consumed power by the device(s). Importantly, the PSV is an actual value that includes measurement and verification of the reduction in consumed power; such measurement and verification methods may be determined by the appropriate governing body or authority for the electric power grid(s). Power Supply Value (PSV) is calculated at the meter or submeter or at building control system or at any device or controller that measures power within the standard as supplied by the regulatory body(ies) that govern the regulation of the grid. PSV variations may depend on operating tolerances, operating standard for accuracy of the measurement. The PSV enables transformation of curtailment or reduction in power at the device level by any system that sends or receives an IP message or power control-related message to be related to or equated to supply as presented to the governing entity that accepts these values and award supply equivalence, for example of a power generating entity or an entity allowed to control power consuming devices as permitted by the governing body of the electric power grid, e.g., FERC, NERC, etc.

PSV may be provided in units of electrical power flow, monetary equivalent, and combinations thereof. Also, PSV relates to the ability to reduce power by curtailment or by putting power back onto the grid, and the quality and value associated therewith. Thus, the PSV provides an actual value that is confirmed by measurement and/or verification, thereby providing for a curtailment value as a requirement for providing supply to the power grid, wherein the supply to the power electric power grid is provided for grid stability, voltage stability, reliability, and combinations thereof, and is further provided as responsive to an energy management system or equivalent for providing grid stability, reliability, frequency as determined by governing authority for the electric power grid and/or grid operator(s).

In an alternative embodiment, additional data may be used to help differentiate each data sample stored in the repository. The additional data is associated with variability factors, such as, for example, outside air temperature, day of the week, time of day, humidity, sunlight, wind speed, altitude, orientation of windows or doors, barometric pressure, energy efficiency rating of the service point, insulation used at the service point, and others. All of these variability factors can have an influence on the power consumption of a device. Some of the variability factor data may be obtained from public sources, such as local, state or national weather services, calendars, and published specifications. Other variability factor data may be obtained privately from user input and from sensors, such as humidity, altitude, temperature (e.g., a thermostat), and optical or light sensors, installed at or near a service point (e.g., within or at a residence or business).

FIG. 2 is a block diagram illustrating how an ALMS operating in accordance with the present invention provides additional operating (e.g., regulating, spinning, and/or non-spinning) reserve to a power utility. Without use of an ALMS operating in accordance with the present invention, the utility has capacity equal to its base load plus its regulating reserve, spinning reserve, and non-spinning reserve as shown on the left side of the figure. However, with use of an ALMS operating in accordance with the present invention, the utility has additional operating reserve, which may be preferably used as regulating, spinning and/or non-spinning reserve (as illustrated in FIG. 2), by drawing power selectively from service points through the interruption or reduction of power to devices, such as air conditioners, furnaces, hot water heaters, pool pumps, washers, dryers, boilers, and/or any other inductive or resistive loads, at the service points.

The present invention can be more readily understood with reference to FIGS. 3-12, in which like reference numerals designate like items. FIG. 3 depicts an exemplary IP-based active load management system (ALMS) 10 that may be utilized by an electric utility, which may be a conventional power-generating utility or a virtual utility, in accordance with the present invention. The below description of the ALMS 10 is limited to specific disclosure relating to embodiments of the present invention. A more general and detailed description of the ALMS 10 is provided in commonly-owned, co-pending U.S. application Ser. No. 11/895,909, which was filed on Aug. 28, 2007, was published as U.S. Patent Application Publication No. US 2009/0062970 A1 on Mar. 5, 2009, and is incorporated herein by this reference as if fully set forth herein. U.S. Patent Application Publication No. US 2009/0062970 A1 provides details with respect to the exemplary operational implementation and execution of control events to interrupt or reduce power to devices located at service points, such as residences and businesses. The use of an ALMS 10 to implement a virtual utility is described in detail in commonly-owned and co-pending U.S. application Ser. No. 12/001,819, which was filed on Dec. 13, 2007, was published as U.S. Patent Application Publication No. US 2009/0063228 A1 on Mar. 5, 2009, and is incorporated herein by this reference as if fully set forth herein.

The ALMS 10 monitors and manages power distribution via an active load director (ALD) 100 connected between one or more utility control centers (UCCs) 200 (one shown) and one or more active load clients (ALCs) 300 (one shown) installed at one or more service points 20 (one exemplary residential service point shown). The ALD 100 may communicate with the utility control center 200 and each active load client 300 either directly or through a network 80 using the Internet Protocol (IP) or any other (IP or Ethernet) connection-based protocols. For example, the ALD 100 may communicate using RF systems operating via one or more base stations 90 (one shown) using one or more wireless communication protocols, such as GSM, ANSI C12.22, Enhanced Data GSM Environment (EDGE), HSPA, LTE, Time Division Multiple Access (TDMA), or CDMA data standards, including CDMA 2000, CDMA Revision A, CDMA Revision B, and CDMA EVDO Rev. A. Alternatively, or additionally, the ALD 100 may communicate via a digital subscriber line (DSL) capable connection, cable television based IP capable connection, or any combination thereof. In the exemplary embodiment shown in FIG. 3, the ALD 100 communicates with one or more active load clients 300 using a combination of traditional IP-based communication (e.g., over a trunked line) to a base station 90 and a wireless channel implementing the HSPA or EVDO protocol from the base station 90 to the active load client 300. The distance between the base station 90 and the service point 20 or the active load client 300 is typically referred to as the “last mile” even though the distance may not actually be a mile. The ALD 100 may be implemented in various ways, including, but not limited to, as an individual server, as a blade within a server, in a distributed computing environment, or in other combinations of hardware and software. In the following disclosure, the ALD 100 will be described as embodied in an individual server to facilitate an understanding of the present invention. Thus, the server embodiment of the ALD 100 described below corresponds generally to the description of the ALD 100 in US Patent Application Publication Nos. US 2009/0062970 A1 and US 2009/0063228 A1.

Each active load client 300 is preferably accessible through a specified address (e.g., IP address) and controls and monitors the state of individual smart breaker modules or intelligent appliances 60 installed at the service point 20 (e.g., in the business or residence) to which the active load client 300 is associated (e.g., connected or supporting). Each active load client 300 is preferably associated with a single residential or commercial customer. In one embodiment, the active load client 300 communicates with a residential load center 400 that contains smart breaker modules, which are able to switch from an “ON” (active) state to an “OFF” (inactive) state, and vice versa, responsive to signaling from the active load client 300. Smart breaker modules may include, for example, smart breaker panels manufactured by Schneider Electric SA under the trademark “Square D” or Eaton Corporation under the trademark “Cutler-Hammer” for installation during new construction. For retro-fitting existing buildings, smart breakers having means for individual identification and control may be used. Typically, each smart breaker controls a single appliance (e.g., a washer/dryer 30, a hot water heater 40, an HVAC unit 50, or a pool pump 70). In an alternative embodiment, IP addressable relays or device controllers that operate in a manner similar to a “smart breaker” may be used in place of smart breakers, but would be installed coincident with the load under control and would measure the startup power, steady state power, power quality, duty cycle and energy load profile of the individual appliance 60, HVAC unit 40, pool pump 70, hot water heater 40, or any other controllable load as determined by the utility or end customer.

Additionally, the active load client 300 may control individual smart appliances directly (e.g., without communicating with the residential load center 400) via one or more of a variety of known communication protocols (e.g., IP, Broadband over PowerLine (BPL) in its various forms, including through specifications promulgated or being developed by the HOMEPLUG Powerline Alliance and the Institute of Electrical and Electronic Engineers (IEEE), Ethernet, Bluetooth, ZigBee, Wi-Fi (IEEE 802.11 protocols), HSPA, EVDO, etc.). Typically, a smart appliance 60 includes a power control module (not shown) having communication abilities. The power control module is installed in-line with the power supply to the appliance, between the actual appliance and the power source (e.g., the power control module is plugged into a power outlet at the home or business and the power cord for the appliance is plugged into the power control module). Thus, when the power control module receives a command to turn off the appliance 60, it disconnects the actual power supplying the appliance 60. Alternatively, the smart appliance 60 may include a power control module integrated directly into the appliance, which may receive commands and control the operation of the appliance directly (e.g., a smart thermostat may perform such functions as raising or lowering the set temperature, switching an HVAC unit on or off, or switching a fan on or off).

The active load client 300 may further be coupled to one or more variability factor sensors 94. Such sensors 94 may be used to monitor a variety of variability factors affecting operation of the devices, such as inside and/or outside temperature, inside and/or outside humidity, time of day, pollen count, amount of rainfall, wind speed, and other factors or parameters.

Referring now to FIG. 4, the ALD 100 may serve as the primary interface to customers, as well as to service personnel, and operates as the system controller sending control messages or power control messages to, and collecting data from, installed active load clients 300 as described in detail below and in U.S. Patent Application Publication No. US 2009/0062970 A1, which is incorporated herein by reference in its entirety. In the exemplary embodiment depicted in FIG. 4, the ALD 100 is implemented as an individual server and includes a utility control center (UCC) security interface 102, a UCC command processor 104, a master event manager 106, an ALC manager 108, an ALC security interface 110, an ALC interface 112, a web browser interface 114, a customer sign-up application 116, customer personal settings 138, a customer reports application 118, a power savings application 120, an ALC diagnostic manager 122, an ALD database 124, a service dispatch manager 126, a trouble ticket generator 128, a call center manager 130, a carbon savings application 132, a utility power and carbon (P&C) database 134, a read meter application 136, a security device manager 140, a device controller 144, and one or more processors 160 (one shown). The operational details of several of the elements of the ALD 100 are described below with respect to their use in connection with the present invention. The operational details of the remaining elements of the ALD 100 may be found in U.S. Patent Application Publication Nos. US 2009/0062970 A1 and US 2009/0063228 A1, and US 2011/0172837, each of which are incorporated herein by reference in their entirety, including specification and figures or drawings, wherein the ALD 100 is also described in the context of an individual server embodiment.

In another embodiment, features, functions and/or components referred to in US Patent Application Publication No. 2010/0161148, Ser. No. 12/715,195 filed Mar. 1, 2010, by inventor Forbes, Jr., which is incorporated herein by reference in its entirety, are combined advantageously with the embodiments described herein.

In one embodiment according to the present invention, a sampling repository is used to facilitate the determination of dispatchable operating reserve power or energy (e.g., spinning and/or regulating reserve) for a utility. An exemplary sampling repository 500 is shown in block diagram form in FIG. 5. As illustrated in FIG. 5, the sampling repository 500 is a means for storing device monitoring data and other data that collectively details how devices (e.g., a hot water heater 40 as shown in FIG. 5) have behaved under specific conditions. The repository 500 may be in various forms, including a matrix, a database, etc. In one embodiment, the sampling repository 500 is implemented in the ALD database 124 of the ALD 100. Alternatively, the sampling repository 500 may reside elsewhere within the ALD 100 or be external to the ALD 100. The sampling repository 500 contains all power consumption data for devices located at a device or service point 20 or within a utility and/or any market participant associated with the electric power grid. Power consumption data may include, but is not limited to: current reading, energy/power used or consumed, energy/power saved, drift or drift rate, power time, user settings for maximum environmental variances, time periods (e.g., hours of the day, days of the week, and calendar days). Taken collectively, this data is used to show how devices behaved during normal operation as well as during control events in which power is temporarily interrupted or reduced to one or more devices. The data may be obtained via passive sampling (e.g., regular monitoring of devices at a particular service point 20 by the active load client 300 associated with the service point 20) and/or active sampling (e.g., direct polling of the devices for the data by the active load client 300 or the ALD 100). As discussed below, the sampling repository 500 is used by the ALD 100 or other components of the ALMS 10 to estimate or project power consumption behavior of the devices and to determine projected power/energy savings resulting from a control event. The projected power savings may be determined using the power savings application 120 based upon the power consumption data in the repository 500.

FIG. 6 is an exemplary screen shot displayed to a user (e.g., customer) during execution of a customer personal settings application 138. The illustrated screen shot shows a screen being used to set the customer preferences for an environmentally-dependent device, such as an HVAC unit 50, a humidifier, or a pool heater. The illustrated screen shot may be provided to the customer in one embodiment via an Internet-accessible web portal 98 (referred to herein as the “customer dashboard”) when such portal is accessed by the customer via a computer, smart phone, or other comparable device. As shown in FIG. 3, the customer dashboard 98 may be connected to the ALD 100 via an Internet service provider for the service point 20 or may be implemented as a customer Internet application 92 when Internet service is supplied through the active load client 300 as described in U.S. Patent Application Publication No. US 2009/0063228 A1. The customer dashboard 98 effectively provides the customer with access into the ALD 100. The ALD's web browser interface 114 accepts inputs from the customer dashboard 98 and outputs information to the customer dashboard 98 for display to the customer. The customer dashboard 98 may be accessed from the service point 20 or remotely from any Internet-accessible device, preferably through use of a user name and password. Thus, the customer dashboard 98 is preferably a secure, web-based interface used by customers to specify preferences associated with devices controlled by the ALD 100 and located at the customer's service point 20, as well as to provide information requested by the customer personal settings application 138 or the customer sign-up application 116 in connection with controlled devices and/or service point conditions or parameters. Customer preferences may include, for example, control event preferences (e.g., times, durations, etc.), bill management preferences (e.g., goal or target for maximum monthly billing cost), maximum and minimum boundary settings for environmental characteristics, and others.

FIG. 7 is another exemplary screen shot displayed to a customer via the customer dashboard 98 during execution of a different portion of the customer personal settings application 138. FIG. 7 shows how customer preferences could be set for an environmentally-independent device, such as a hot water heater 40, a pool pump 70, or a sprinkler system water pump (which may also be an environmentally-dependent device if it includes, for example, a rainfall sensor). Using the web browser interface 114, customers interact with the ALD 100 and specify customer personal settings 138 that are recorded by the ALD 100 and stored in the ALD database 124 or other repository 500. The personal settings 138 may specify time periods during which load control events are permitted, time periods during which load control events are prohibited, maximum allowable variances for an operating environment at a particular service point 20 (e.g., maximum and minimum temperature and/or humidity), normal operating conditions of devices at different times of day, and other personal preferences related to operation of devices under the control of the ALD 100 through the active load client 300 at the service point 20.

As alluded to above, the present invention optionally tracks and takes into account the “drift” of an environmentally-dependent device. Drift occurs when the environmental characteristic(s) (e.g., temperature) monitored by an environmentally-dependent device begins to deviate (e.g., heat up or cool down) from a set point that is to be maintained by the environmentally-dependent device. Such deviation or drift may occur both normally and during control events. Thus, drift is the time it takes for the monitored environmental characteristic to move from a set point to an upper or lower comfort boundary when power, or at least substantial power, is not being consumed by the device. In other words, drift is a rate of change of the monitored environmental characteristic from a set point without use of significant power (e.g., without powering an HVAC unit compressor, but while continuing to power an associated digital thermostat and HVAC unit control system). One of ordinary skill in the art will readily appreciate that devices, such as HVAC units 50, which control one or more environmental characteristics at a service point 20, are also influenced or affected by the environment at the service point 20 because their activation or deactivation is based on one or more sensed environmental characteristics at the service point 20. For example, an HVAC unit 50 in cooling mode that attempts to maintain an inside temperature of 77 .degree. F. activates when the inside temperature is some temperature greater than 77 .degree. F. and, therefore, is influenced or affected by the environment in which the HVAC unit 50 operates.

The inverse of drift is “power time,” which is the time it takes for the sensed environmental characteristic to move from a comfort boundary to a set point when significant or substantial power is being supplied to the environmentally-dependent device. In other words, “power time” is a rate of change of the monitored environmental characteristic from a comfort boundary to a set point with significant use of power. Alternatively, “drift” may be considered the time required for the monitored environmental characteristic to move to an unacceptable level after power is generally turned off to an environmentally-dependent device. By contrast, “power time” is the time required for the monitored environmental characteristic to move from an unacceptable level to a target level after power has been generally supplied or re-supplied to the environmentally-dependent device.

The power consumption data for an environmentally-dependent device, which may be gathered actively or passively as described above, may be used to empirically determine the drift and power time (rate of change, temperature slope, or other dynamic equation (f{x})) that defines an environmental characteristic's variation at a service point 20, or at least within the operating area of the environmentally-dependent device, so as to permit the determination of a uniquely derived “fingerprint” or power usage/consumption pattern or behavior for the service point 20 or the environmentally-dependent device.

Customers define the upper and lower boundaries of comfort by inputting customer preferences 138 through the web browser interface 114, with the set point optionally being in the middle of those boundaries. During normal operation, an environmentally-dependent device will attempt to keep the applicable environmental characteristic or characteristics near the device's set point or set points. However, all devices, whether environmentally-dependent or environmentally-independent, have a duty cycle that specifies when the device is in operation because many devices are not continuously in operation. For an environmentally-dependent device, the duty cycle ends when the environmental characteristic(s) being controlled reaches the set point (or within a given tolerance or variance of the set point). After the set point has been reached, the environmentally-dependent device is generally turned off and the environmental characteristic is allowed to “drift” (e.g., upward or downward) toward a comfort boundary. Once the environmental characteristic (e.g., temperature) reaches the boundary, the environmentally-dependent device is generally activated or powered on again until the environmental characteristic reaches the set point, which ends the duty cycle and the power time.

Drift may also occur during a control event. A control event is an action that temporarily reduces, terminates, or otherwise interrupts the supply of power to a device. During a control event, the environmental characteristic (e.g., temperature) monitored and/or controlled by an environmentally-dependent device will drift toward a comfort boundary (e.g., upper or lower) until the environmental characteristic reaches that boundary. Once the environmental characteristic reaches the boundary, the ALMS 10 generally returns or increases power to the device to enable the environmental characteristic to reach the set point again.

For example, an HVAC unit 50 may have a set point of 72 .degree. F. and minimum and maximum comfort boundary temperatures of 68 .degree. F. and 76 .degree. F., respectively. On a cold day, a control event may interrupt power to the HVAC unit 50 causing the monitored temperature within the service point 20 to move toward the minimum comfort boundary temperature. Once the monitored temperature inside the service point 20 reaches the minimum comfort boundary temperature, the control event would end, and power would be restored or increased to the HVAC unit 50, thus causing the monitored temperature to rise toward the set point. A similar, but opposite effect, may take place on a warm day. In this example, “drift” is the rate of change with respect to the time it takes the HVAC unit 50 to move from the set point to either the upper or lower comfort bounds. Analogously, “power time” is the rate of change with respect to the time required for the HVAC unit 50 to move the monitored temperature from the upper or lower comfort bounds to the set point. In one embodiment of the present invention, drift and power time are calculated and recorded for each environmentally-dependent or environmentally-independent device or for each service point 20.

In another embodiment, drift and other measurement data available from the ALD database 124 are used to create a power consumption behavior or pattern for each environmentally-dependent or environmentally-independent device or for each service point 20. The other measurement data may include vacancy times, sleep times, times in which control events are permitted, and/or other variability factors.

The environment within an energy-efficient structure will have a tendency to exhibit a lower rate of drift. Therefore, environmentally-dependent devices operating within such structures may be subject to control events for longer periods of time because the amount of time taken for the monitored environmental characteristic to reach a comfort boundary due to drift after being set to a set point is longer than for less efficient structures.

In another embodiment, the ALD 100 may identify service points 20 that have an optimum drift for power savings. The power savings application 120 calculates drift for each service point 20 and/or for each environmentally-dependent device at the service point 20, and saves the drift information in the ALD database 124 as part of power consumption data for the device and/or the service point 20. Thus, power saved as a result of drift during a control event increases overall power saved by the environmentally-dependent device at the service point 20.

FIG. 8 illustrates an exemplary operational flow diagram 800 providing steps executed by the ALD 100 to empirically analyze power usage of devices and populate a repository 500 with data samples resulting from such power usage analysis, in accordance with one embodiment of the present invention. The steps in FIG. 8 may be considered to implement a passive sampling algorithm. The steps of FIG. 8 are preferably implemented as a set of computer instructions (software) stored in memory (not shown) of the ALD 100 and executed by one or more processors 160 of the ALD 100.

According to the logic flow, the active load client 300 polls devices within the service point 20, such as a washer/dryer 30, hot water heater 40, HVAC unit 50, smart appliance 60, pool pump 70, or other devices within the service point 20, and obtains current readings. Upon receiving the current reading data from the active load client 300, the ALC interface 112 sends the data to the ALC manager 108. The ALC manager 108 stores the data to the sampling repository 500, which may be implemented in the ALD database 124 using the operational flow illustrated in FIG. 8.

The following information may be provided as parameters to the operational flow of FIG. 8: an identification (ID) of the device, temperature mode (either “heating” or “cooling”), duty cycle, current temperature read by the device, and previous temperature read by the device. Each temperature reading includes a device ID, a set point (which is only useful for environmentally-dependent devices), and variability factor measurement data (as described previously).

Initially, the ALD 100 determines (802) whether the device used any, or at least any appreciable amount of, energy. If not, then the logic flow ends. Otherwise, the ALD 100 determines (804) the time duration of the data sample, the time duration when the device was on, and the time duration when the device was off based on the data sample. Next, the ALD 100 determines (806) whether the received data comes from an environmentally-dependent device or an environmentally-independent (e.g., binary state) device. If the received data comes from an environmentally-dependent device, then the ALD 100 determines (808) the energy used per minute for the device, and determines (810) whether the device is drifting or powering. The ALD 100 determines that the device is drifting if the environmental characteristic monitored by the device is changing in a manner opposite the mode of the device (e.g., the room temperature is rising when the device is set in cooling mode or the room temperature is decreasing when the device is set in heating mode). Otherwise, the device is not drifting.

If the device is drifting, then the ALD 100 determines (814) the drift rate (e.g., degrees per minute). On the other hand, if the device is not drifting, then the ALD 100 determines (812) the power time rate. Once either the drift rate or the power time rate has been calculated, the ALD 100 determines (880) whether there is already a record in the sampling repository 500 for the device being measured under the present operating conditions of the device (e.g., set point and other variability factors (e.g., outside temperature)). If there is no existing record, then the ALD 100 creates (882) a new record using, for example, the device's ID, time of record, current set point, current outside temperature, energy used per minute, power time rate, and drift rate (assuming that either a power time rate or a drift rate has been determined). However, if there is an existing record, then the ALD 100 updates (884) the existing record by averaging the new data (including energy usage, drift rate, and power time rate) with the existing data and storing the result in the repository 500.

If the ALD 100 determines (806) that the received data comes from an environmentally-independent device, then the ALD 100 determines (842) the energy used per minute for the device and further determines (844) the energy saved per minute for the device. The ALD 100 then searches the repository 500 (e.g., ALD database (124)) to determine (890) whether there is already a record for the device for the applicable time period. If there is no existing record, then the ALD 100 creates (892) a new record using the device's ID, time of record, current time block, energy used per minute, and energy saved per minute. However, if there is an existing record, then the ALD 100 updates (894) the existing record by averaging the new data (including energy usage and energy savings) for the time block with the existing data for the time block and stores the result in the repository 500. For environmentally-independent devices, energy usage and energy savings are saved with respect to a block or period of time.

FIG. 9 illustrates an exemplary operational flow diagram 900 providing steps executed by the ALD 100 to project or estimate the energy usage expected of a device during a future time period in a given environment setting, in accordance with one embodiment of the present invention. The steps of FIG. 9 are preferably implemented as a set of computer instructions (software) stored in memory (not shown) of the ALD 100 and executed by one or more processors 160 of the ALD 100. In accordance with one embodiment, the operational flow of FIG. 9 may be executed by the power savings application 120 of the ALD 100 when a utility operator, or other operator of the ALD 100, wants to project the energy usage for a device over a specified time period in the future, such as during a period of time in which a control event is to occur.

The following information may be provided as parameters to the operational flow of FIG. 9: the device ID, the start time of the future time period, the end time of the future time period, the manage mode of the device, and, for an environmentally-independent device, a binary control factor. The manage mode is either “control” or “normal” to indicate whether the device is being measured during a control event or during normal operation, respectively. The binary control factor is preferably utilized for environmentally-independent devices and represents the duty cycle of the device. For example, if a water heater 40 runs at 20% duty cycle, the binary control factor is 0.2.

Initially, the ALD 100 (e.g., power savings application 120) determines (902) a future time period based on the start and stop times. The future time period may be set by the utility implementing the load control procedure of the present invention or a second utility that has requested delivery of operating reserve power from the utility implementing the load control procedure of the present invention. After the time period at issue is known, the power savings application 120 begins the procedure for projecting or estimating the amount of power that can be saved as the result of execution of a control event during the future time period. Accordingly, the power savings application 120 analyzes the devices to be controlled during the control event. Thus, the power savings application 120 determines (904) whether the devices include both environmentally-dependent and environmentally-independent (e.g., binary state) devices. For each environmentally-dependent device, the power savings application 120 determines (920) whether the device is in environment controlling (e.g., heating or cooling) mode. Next, the power savings application 120 retrieves (922) the anticipated set points for the device during the future time period of the control event and obtains (924) information regarding the outside environmental characteristic(s) (e.g., the outside temperatures) expected during the control event time period. The power savings application 120 then makes projections (926) about the device's expected power consumption behavior during the future time period. In one embodiment, the projection determination of block 926 is implemented using a best match algorithm, as described in detail below with respect to FIG. 10, to find stored repository records that best match the behavior of the device for each combination of set points, outside environmental characteristics (e.g., temperatures), and time periods, as measured and stored using the logic flow of FIG. 8. The power consumption behavior of the device is used to determine the amount of energy that would be expected to be used by the device if the control event did not occur and, thus, the amount of energy estimated or expected to be saved per unit time during the control event. The power savings application 120 multiplies (928) the saved power per unit time by the time duration of the future control event to determine the total amount of energy projected to be used by the device in the absence of the control event. The power savings application returns (980) the total projected amount of energy used by the device in the absence of the proposed control event.

However, if the power savings application 120 determines (904) that the proposed control event is to affect an environmentally-independent device, then the power savings application 120 determines (960) whether the device is currently scheduled to be on or off during the proposed time period of the control event. Next, the power savings application 120 creates, obtains, or otherwise determines (962) a list of time blocks for the specified control event time period. The power savings application 120 then makes projections (964) about the device's power consumption behavior during the future, control event time period. In one embodiment, the projection determination of block 964 is implemented using a best match algorithm, as described in detail below with respect to FIG. 10, to find stored repository records that best match the behavior of the device for each combination of set points, outside environmental characteristics (e.g., temperatures), and time periods, as measured and stored using the logic flow of FIG. 8. The power consumption behavior of the device is used to determine the amount of energy that would be expected to be used by the device if the control event did not occur and, thus, the amount of energy estimated or expected to be saved per unit time during the control event. Next, the power savings application 120 multiplies (968) the saved power per unit time by the time duration of the future control event to determine the total amount of energy projected to be used in the absence of the control event. If the projected energy savings is based on power consumption during a previous control event (970), then the power savings application 120 multiplies (972) the total amount of energy times the binary control factor to determine the amount of energy projected to be used by the device in the absence of the control event. The power savings application returns (980) the total projected amount of energy used by the device in the absence of the proposed control event.

One or ordinary skill in the art will readily recognize and appreciate that the operational flow of FIG. 9 may be used for each controlled device at a service point, for the controlled devices at multiple service points, or for all the controlled devices at all the service points supplied or supported by a utility. The total projected energy usage by the devices may be aggregated across a single service point, for all service points within a group, and/or for all groups served by the utility.

FIG. 10 illustrates an exemplary operational flow diagram 1000 providing steps executed by the ALD 100 for estimating power consumption behavior of a device in accordance with an exemplary embodiment of the present invention. The algorithm or operational flow illustrated in FIG. 10 provides one embodiment for implementing steps 926 and 964 of FIG. 9. The operational flow of FIG. 10 determines which record or records in the sampling repository 500 provides the closest match to a given environment or operational setting for use in projecting device energy usage/savings during a time period of a future control event, in accordance with one embodiment of the present invention. The steps of FIG. 10 are preferably implemented as a set of computer instructions (software) stored in memory (not shown) of the ALD 100 and executed by one or more processors 160 of the ALD 100. The operational flow of FIG. 10 may be initiated by the ALD 100 when trying to identify or determine the sampling repository record or records that best match the power consumption behavior of a device in a specific setting.

In one embodiment, the operational flow of FIG. 10 is called during execution of the operational flow of FIG. 9 as noted above. When so called, the operational flow of FIG. 9 provides the operational flow of FIG. 10 with parameters that indicate the type of records to be searched. These parameters include, but are not limited to: a device ID, a duty mode (either on or off), a time period (e.g., corresponding to the time period of the proposed future control event), a set point delta, a delta or variance related to one or more environmental characteristics (e.g., outside temperature), and a time block delta. Duty mode signifies the duty cycle of the device. If the duty mode is TRUE or ON, significant power is being consumed. If the duty mode is FALSE or OFF, significant power is not being consumed (i.e., power is being saved). Duty cycle exists for switch-controlled, binary state, or environmentally-independent devices which go ON and OFF irrespective of the influence or affect of environment. For HVAC devices 50, duty mode is always ON. Set point delta is the amount a set point may be varied during a search in order to find a matching repository record. Outside temperature/environmental characteristic delta is the number of temperature degrees or other change in environmental characteristics over which data relating to the outside temperature or other environmental characteristics may be varied during a search in order to find a matching repository record. Time block delta is the amount of time a time block may be varied during a search in order to find a matching repository record.

Initially, the ALD 100 determines (1002) whether the requested repository search relates to an environmentally-dependent device or an environmentally-independent device. If the search relates to an environmentally-dependent device, then the ALD 100 attempts to find (1004) power consumption records in the sampling repository 500 that match the device ID, duty mode, environmental characteristic (e.g., temperature) set point, and associated outside environmental characteristic data. Power consumption records include power consumption data, such as power consumed, current drawn, duty cycle, operating voltage, operating impedance, time period of use, set points, ambient and outside temperatures during use (as applicable), and/or various other energy use data. If a record exists that matches all the power consumption search criteria, such record would be considered the record that most closely matches the given environment setting. If no exact match is found (1010), then the ALD 100 begins looking for records that slightly differ from the given environment setting. In one embodiment, the ALD 100 incrementally increases or decreases (1012) the environment-related search criteria (e.g., temperature set point and/or outside/ambient temperature) using the set point delta and the outside temperature/environmental characteristic delta as a guide to look for relevant records. Such incremental/iterative modification of the search criteria continues until either relevant records are found or some applicable limit (e.g., as indicated by the set point delta and/or other parameter deltas) is reached.

If the ALD 100 determines (1002) that the search relates to an environmentally-independent device, then the ALD 100 attempts to find (1040) power consumption records in the sampling repository 500 that match the device ID, duty mode, and time of operation (corresponding to the expected, future time of the control event). If a record is not found that matches all the search criteria (1070), then the ALD 100 modifies its search to look for records that slightly differ from the given environment setting. In one embodiment, the ALD 100 modifies its search by incrementally increasing or decreasing (1072) the time of operation for a given duty mode. The iterative searching continues until either relevant records are found or some applicable limit (e.g., as indicated by the time block delta or other parameter deltas) is reached. Any records that were found as a result of the search are provided (1060) to the requesting program (e.g., the operational flow of FIG. 9). The result of the operational flow of FIG. 10 is a set of one or more power consumption records from the sampling repository 500 that are the closest match to the given environment or proposed control event setting.

FIG. 11 illustrates an exemplary operational flow diagram 1100 providing steps executed by the ALD 100 to project energy savings through power interruption or reduction to a device during a control event, in accordance with one embodiment of the present invention. The steps of FIG. 11 are preferably implemented as a set of computer instructions (software) stored in memory (not shown) of the ALD 100 and executed by one or more processors 160 of the ALD 100. As with the operational flow of FIG. 9, the operational flow of FIG. 11 may be executed by the power savings application 120 when an operator of the utility or of the ALD 100 wants to project the energy savings for a device over a specified time period during operation of a control event.

The following information may be provided as parameters to the operational flow of FIG. 11: a device ID, a start time of the control event, an end time of the control event, and a binary control factor, as described above in connection with FIG. 9. Initially, the ALD 100 (e.g., power savings application 120) projects (1102) the energy usage/power consumption for the device during normal operation within the expected time period of the control event using, for example, the operational flow of FIG. 9. Next, the power savings application 120 projects (1104) the power consumption for the device during the control event using, for example, the operational flow of FIG. 9. For example, depending on the duty cycle, set points, drift or drift rate, power time, and other parameters for the device, the device may be projected to be on and consuming power for some amount of time during the time period of the control event. Thus, both the expected amount of power consumed during normal operation (i.e., in the absence of any control event) and the expected amount of power consumed during the control event are determined to accurately assess any possible power savings as a result of the control event. After the two projected power consumption values have been determined, the power savings application 120 calculates (1106) the difference between the two values, which is the projected power consumption for the device during the control event time period. Because the projected power consumption will not be realized during the control event, such power consumption corresponds directly to an amount of energy saved during the control event. The power savings application 120 returns (1108) the projected energy savings value. One of ordinary skill in the art will readily recognize and appreciate that the power savings application 120 may aggregate the projected power savings for all controlled devices at a service point 20, for all controlled devices at service points within a group, or for controlled devices within all service point groups served by the utility to obtain an aggregate amount of power savings as a result of a control event.

Another context in which the ALMS 10 may be utilized is in conjunction with other renewable energy sources. A number of renewable energy sources, such as wind power and solar power, are variable in nature. That is, such energy sources do not generate power at a constant rate. For example, wind increases or decreases from moment to moment. Wind turbines can generate a large amount of power due to large winds or can stop generating completely due to lack of any wind. Solar panels may be able to generate a great deal of power on very sunny days, a little power on cloudy days, and virtually no power at night.

As a result, power utilities that make use of renewable energy must compensate for the under-generation or over-generation of power from those sources. When renewable energy sources are under-generating, the ALMS 10 may utilize the processes disclosed above to provide additional operating reserve to compensate for the lack of power generation by the renewable energy source and for the effects resulting therefrom, including output frequency instability. For example, a utility utilizing wind or solar energy sources may further incorporate the ALMS 10 into the utility distribution system to provide regulating reserve during time periods of under-generation.

FIG. 12 is a graph that depicts the “load profile” of a utility over a predetermined time period, showing actual energy usage as well as projected energy usage determined with and without a control event in accordance with an exemplary embodiment of the present invention. The load profile graph depicts the following:

a. Baseline power consumption 1202. This is the total possible load of, or power consumed by, all controlled devices over a specified period of time.

b. Projected interruptible load usage 1204 (i.e., projected load or energy usage with a control event) for all controlled devices at all service points (or at selected service points) served by the utility in the absence of a control event. The projected interruptible load usage may be determined in one embodiment through execution of the operational flow of FIG. 9. The projected interruptible load available 1204 indicates the load for all controlled devices if they are controlled 100% of the time using customer preferences.

c. Projected interruptible load available 1206 (i.e., projected energy used when no control events are used) for all controlled devices at all service points (or at selected service points) served by the utility during a control event. The projected interruptible load usage may be determined in one embodiment through execution of the operational flow of FIG. 11.

d. Actual interruptible load usage 1208 for all controlled devices at all service points (or at selected service points) served by the utility. The actual interruptible load usage 1208 is the power that is currently being used by all controlled devices. This type of load profile graph may be generated for all controlled devices at a service point 20, for controlled devices at all service points within a group, or for controlled devices at all groups served by the utility.

In the load profile graph of FIG. 12, the capacity under contract is shown as a straight double line at the top of the graph and indicates the baseline power consumption 1202. The baseline power consumption 1202 represents the total amount of power that the utility is obligated to provide. The actual interruptible load usage 1208 is the actual energy usage of all devices controlled by the utility. The projected interruptible load usage 1204 at the bottom of the load profile graph is the projected energy used when control events are used, and the projected interruptible load available 1206 is the projected energy usage when control events are not used. The difference between the projected interruptible load usage 1204 and the projected interruptible load available 1206 is the capacity that may be used for operating reserve, including regulating reserve, spinning reserve, and non-spinning reserve.

Normally, when a utility observes energy demand that is near its peak capacity, it will attempt to initiate control events for customers who voluntarily participate in power saving programs (i.e., flexible load-shape programs, as described earlier). Typically, these control events will provide sufficient capacity to prevent the utility from using non-spinning reserve. However, there are situations in which a sufficient number of customers may have manually decided to opt out of power saving programs and, as a result, the utility would be unable to recover enough energy to meet its spinning reserve needs from its remaining customers who voluntarily participate in the program. Such a situation could happen, for instance, on a very hot day when many people are home, such as on a holiday or a day over the weekend. In such a case, the utility would still be in danger of using non-spinning reserve or even running out of reserve capacity altogether. In such a situation, the utility would be in a “critical control” mode. In critical control mode, the utility may override all customer preferences, including both those who voluntarily participate in power saving programs and those who do not. During periods of critical control, the utility may utilize the ALD 100 to adjust settings of environmentally-dependent devices to settings outside of normal comfort preferences (but not life-threatening). Invoking critical control enables a utility to return power demand to acceptable levels.

Use of the ALMS 10 may help a utility mitigate the likelihood of critical control situations. For example, whenever a customer overrides or opts out of a control event, the ALMS 10, using the techniques disclosed herein, finds additional customers who may be the target of a voluntary control event. Analogously, when controlled devices that are participating in a control event are required to exit the control event due to customer preferences (e.g., the amount of time that the customer's devices may participate in a control event), the ALD 100 may release such devices from the control event and replace them with other voluntarily controlled devices. The replacement devices would then preferably supply, through deferment, at least the same amount of reserve power as was being sourced by the devices that were released from the control event. Thus, the system 10 of the present invention increases the likelihood that a utility will be able to spread control events to other customers before invoking critical control.

In a further embodiment, the entire ALMS 10 described in FIG. 3 may also be implemented in a proprietary network that is IP-based, real-time, temperature-derived, verifiable, interactive, two-way, and responsive to Automatic Generation Control (AGC) commands to produce operating reserve power through implementation of control events.

In an additional embodiment of the present invention, the sampling data stored in the repository 500 using the operational flow of FIG. 5 could also include other factors (called “variability factors”) related to power consumption, such as day of the week, humidity, amount of sunshine, or number of people in the household. This additional data would allow the projected energy usage and projected energy savings to be more accurate based on these additional factors. To make use of this data, the ALD 100 may obtain the additional data from sources within and/or external to the ALMS 10, such as weather databases, live weather feeds from sources such as National Weather Reporting stations, outdoor sensors 94, or any weather related input device commercially available on a real time or predictive basis, calendars, and voluntary customer feedback. Some of the variability factor measurements are available from public sources, while others are available via private sources.

In another alternative embodiment of the present invention, transmission line loss may be included in the projected energy savings determination of FIG. 11. As those of ordinary skill in the art will recognize and appreciate, the amount of power supplied by a utility to source a device remote from the utility equals the amount of power required by the device plus the amount of power lost in the transmission lines between the utility's power generation plant and the location of the device. Thus, the projected energy savings resulting from a control event may be determined by determining an amount of power expected to be consumed by the controlled device or devices at a service point, at multiple service points or throughout the entire service area of the utility during the time period of the control event absent occurrence of the control event to produce first energy savings, determining an amount of power that is not expected to be dissipated in transmission lines as a result of not delivering power to the controlled device or devices during the control event to produce second energy savings, and summing the first energy savings and the second energy savings.

In a further embodiment of the present invention, the operating reserve (e.g., spinning reserve or regulating reserve) determined by a utility using the techniques disclosed above can be sold to a requesting utility 1306, as illustrated in FIG. 13, which is essentially a replication of FIG. 9 of U.S. Patent Application Publication No. US 2009/0063228 A1, which is incorporated herein by reference in its entirety. As explained in U.S. Patent Application Publication No. US 2009/0063228 A1, the saved power may then be distributed to the requesting utility 1306 after commencement of the control event (e.g., during and/or after completion of the control event) conducted by the selling utility. The selling utility may be a virtual utility 1302 or a serving utility 1304 as illustrated in FIG. 13 and described in detail in U.S. Patent Application Publication No. US 2009/0063228 A1, which is incorporated herein by reference in its entirety. Alternatively, a third party may serve as a managing entity to manage operation of the ALMS 10 and the resultant distribution of operating reserve to a requesting utility 1306 subsequent to commencement of a control event.

In yet another embodiment, the ALD 100 for a utility may determine projected energy savings for each service point 20 served by the utility in accordance with the operational flow of FIG. 11 and aggregate the projected energy savings across all service points served by the utility to obtain the total projected energy savings from which operating reserve may be determined as described above.

In a further embodiment, instead of or in addition to using the operational flow of FIG. 10 in an attempt to find a best match data point in the repository 500 for use in estimating power consumption behavior of a device when the time period of the control event does not correspond to a time period in the repository 500, the ALD 100 may determine whether the repository 500 includes power consumption data for the device during time periods before and after the expected time period of the control event and, if so, interpolate a value corresponding to an amount of power expected to be consumed by the device during the time period of the control event based on the power consumption data for the device during the time periods before and after the expected time period of the control event. However, more preferably, the power supply value (PSV) associated with each of the at least one power consuming device(s) is used to determine or generate the power consumption behavior and commercial value for the response to the control event associated with the power consuming device(s).

The present invention provides systems and methods that receive electric power from an electric power grid, the systems and methods including: at least one power consuming device that requires electric power to operate; at least one controllable device operably coupled to the at least one power consuming device, the at least one controllable device operable to control a flow of grid-supplied electric power to the at least one power consuming device responsive to power control instructions, wherein each of the at least one power consuming devices has a corresponding power supply value (PSV); a backup power subsystem operably coupled to the at least one power consuming device, the backup power subsystem operable to automatically supply electric power to the at least one power consuming device when a flow of grid-supplied electric power to the at least one power consuming device drops below a threshold; and a client device operable to receive power control messages from a remote system control component and provide power control instructions to the at least one controllable device responsive to the power control messages, wherein a first received power control message instructs the client device to disable a flow of grid-supplied electric power to the at least one power consuming device, and wherein a first power control instruction instructs the at least one controllable device to disable the flow of grid-supplied electric power to the at least one power consuming device and causing activation of the backup power subsystem.

Also, systems and methods for a client device at a base transceiver site to control a flow of electric power from an electric power grid to a collocated base transceiver system so as to provide operating reserve for to the electric power grid, the base transceiver system including at least one base transceiver unit operable to provide wireless communication capability, a controllable device operable to control a flow of grid-supplied electric power to the at least one base transceiver unit, and a backup power subsystem operable to supply electric power to the at least one base transceiver unit when a flow of grid-supplied electric power to the at least one base transceiver unit drops below a threshold, the method including the steps of: receiving power control messages from a remote system control component, at least a first received power control message instructing the client device to disable a flow of grid-supplied electric power to the at least one base transceiver unit; and providing a first power control instruction to the at least one controllable device responsive to the first received power control message, the first power control instruction instructing the at least one controllable device to disable a flow of grid-supplied electric power to the at least one base transceiver unit, thereby causing activation of the backup power subsystem, wherein an amount of grid-supplied electric power saved as a result of disabling a flow of grid-supplied electric power to the at least one base transceiver unit provides operating reserve for the electric power grid.

Also, in another embodiment, method for a client device located at an electrical service point to control a flow of electric power from an electric power grid to the service point so as to provide operating reserve to the electric power grid, the service point including at least one power consuming device operable to consume electric power, at least one controllable device operable to control a flow of grid-supplied electric power to the at least one power consuming device, and a backup power subsystem operable to supply electric power to the at least one power consuming device when a flow of grid-supplied electric power to the at least one power consuming device is reduced below a threshold, the method including the steps of: receiving power control messages from a remote system control component, at least a first power control message instructing the client device to disable a flow of grid-supplied electric power to the at least one power consuming device; and providing a first power control instruction to the at least one controllable device responsive to the first power control message, the first power control instruction instructing the at least one controllable device to disable a flow of grid-supplied electric power to the at least one power consuming device, thereby causing activation of the backup power subsystem, wherein an amount of grid-supplied electric power saved as a result of disabling a flow of grid-supplied electric power to the at least one power consuming device provides operating reserve for the electric power grid based upon a power supply value (PSV) associated with each of the at least one power consuming device(s).

In yet another embodiment, a requesting utility may utilize a method for acquiring operating reserve power from a sourcing utility. According to this embodiment, the requesting utility requests operating reserve power from the sourcing utility sufficiently in advance of a transfer time at which the operating reserve power will be needed so as to facilitate measurable and verifiable load-controlled generation of the operating reserve power. The load-controlled generation of the operating reserve power results from a determination of operating reserve as detailed above with respect to FIGS. 7-12. The requesting utility receives an acknowledgment from the sourcing utility indicating that the sourcing utility will supply the operating reserve power at the transfer time. Then, at the transfer time and for a time period thereafter, the requesting utility receives at least some of the operating reserve power from the sourcing utility.

In a further embodiment, the operating reserve determination techniques may be utilized by a virtual utility 1302 as disclosed in U.S. Patent Application Publication No. US 2009/0063228 A1, which is incorporated herein by reference in its entirety. For example, the virtual utility 1302 may be operable to at least offer energy to one or more requesting utilities 1306 for use as operating reserve for the requesting utilities 1306. In such a case, the virtual utility 1302 may include, among other things, a repository 500 and a processor 160 (e.g., within an ALD 100). In this embodiment, the processor 160 is operable to remotely determine, during at least one period of time, power consumed by at least one device to produce power consumption data. The processor 160 is further operable to store the power consumption data in the repository 500 and, at the appropriate time, determine an expected, future time period for a control event during which power is to be reduced to the device or devices. The processor 160 is also operable to estimate, prior to commencement of the control event, power consumption behavior expected of the device or devices during the time period of the control event based at least on the stored power consumption data. The processor 160 is further operable to determine, prior to commencement of the control event, projected energy savings resulting from the control event based at least on the estimated power consumption behavior of the device or devices. Still further, the processor 160 is operable to determine, prior to commencement of the control event, operating reserve based on the projected energy savings. After determination of the operating reserve, the processor 160 is operable to communicate an offer to supply the operating reserve to a requesting utility 1306 or utilities.

As described above, the present invention encompasses a system and method for determining operating reserve capacity using an ALD or comparable device, software, or combination thereof so that the operating reserve capacity may be made available to the power utility that generated the operating reserve through load control or to the power market generally (e.g., via the FERC grid). When a utility requires power beyond its native load, the utility must make use of its operating reserve or acquire the additional power via the FERC grid from other utilities. As discussed above, one type of operating reserve is spinning reserve. Spinning reserve is additional generating capacity that is already connected to the power system and, thus, is almost immediately available. In accordance with one embodiment of the present invention, the ALD makes spinning reserve available to a utility. Thus, through use of the ALD, a utility (power generating utility or a virtual utility) can determine or project spinning reserve or other operating reserve that is available through interruptible power savings at service points. The spinning reserve is measurable and verifiable, and can be projected for a number of days in advance, and such projections can be sold to other utilities on the open market.

As disclosed above, the ALD 100 may be considered to implement a type of flexible load-shape program. However, in contrast to conventional load control programs, the load-shape program implemented by the ALD 100 projects an amount of operating reserve resulting from selective control of devices (loads) based on known, real-time customer preferences. In addition, due to its communication and control mechanisms, the ALD 100 can project power savings, as well as operating reserve (e.g., regulating, spinning and/or non-spinning reserve) that is active, real-time, verifiable, and measurable so as to comply with protocols and treaties established for the determination of carbon credits and offsets, as well as renewable energy credits. The information acquired by the ALD 100 is not simply samples of customer preferences and data, but actual power consumption information.

In yet another embodiment, the at least one power consuming device is at least one of a data center, a mobile switching center, and a central telephone office switch.

In a further embodiment, the backup power subsystem is at least one of a battery backup system, a backup generator system, a backup solar power system, and a backup hydrogen fuel cell system.

In the foregoing specification, the present invention has been described with reference to specific embodiments. However, one of ordinary skill in the art will appreciate that various modifications and changes may be made without departing from the spirit and scope of the present invention as set forth in the appended exemplary claims. For example, the passive sampling algorithm of FIG. 8, the projected energy usage algorithm of FIG. 9, the best sampling match algorithm of FIG. 10, and the projected energy savings algorithm of FIG. 11 may be performed by one or more equivalent means. Accordingly, the specification and drawings are to be regarded in an illustrative rather than a restrictive sense, and all such modifications are intended to be included within the scope of the present invention.

Benefits, other advantages, and solutions to problems have been described above with regard to specific embodiments of the present invention. However, the benefits, advantages, solutions to problems, and any element(s) that may cause or result in such benefits, advantages, or solutions to become more pronounced are not to be construed as a critical, required, or essential feature or element of any or all the claims. The invention is defined solely by the appended claims including any amendments made during the pendency of this application and all equivalents of those claims as issued.

Claims

1. A system for managing power on an electric power grid, comprising: at least one power consuming device, at least one controllable device, and at least one client device constructed and configured in network communication;wherein the at least one controllable device is operably coupled to the at least one power consuming device;wherein the at least one controllable device is operable to control a power flow from the electric power grid to the at least one power consuming device responsive to power control instructions from the at least one client device;wherein the at least one power consuming device has an actual value of power reduced based on revenue grade metrology, and confirmed by measurement and verification; andwherein the actual value of power reduced is a curtailment value as supply equivalence and provides operating reserve for the electric power grid.
2. The system of claim 1, further comprising a remote system control component, and wherein the remote system control component is operable for aggregating the actual value of power reduced and/or to be reduced from each of the at least one power consuming device.
3. The system of claim 2, wherein the remote system control component is utility server.
4. The system of claim 1, wherein the at least one client device is integrated into a smart meter.
5. The system of claim 1, further comprising a backup power subsystem operable to automatically supply electric power to the at least one power consuming device when the power flow from the electric power grid to the at least one power consuming device drops below a threshold.
6. The system of claim 5, wherein the backup power subsystem comprises at least one of a battery backup system, a backup generator system, a backup solar power system, and a backup hydrogen fuel cell system.
7. The system of claim 1, wherein the client device is further operable to communicate with the at least one controllable device and the at least one power consuming device via at least one of Internet Protocol, Bluetooth, Broadband over PowerLine (BPL), ZigBee, High Speed Packet Access (HSPA), Evolution for Data Only (EVDO), Wi-Fi, 4G, Long Term Evolution (LTE) and its derivative standards.
8. The system of claim 1, wherein the at least one client device is further operable to communicate with the at least one controllable device and the at least one power consuming device via at least one of Ethernet solution, wireless or wired communication.
9. The system of claim 1, wherein the at least one power consuming device comprises at least one environmentally-dependent device, wherein the at least one environmentally-dependent device comprises at least one of a washer, a dryer, a hot water heater, a pool pump, and a smart appliance.
10. The system of claim 9, wherein the smart appliance is integrated with a power control module, and wherein the power control module is selected from the group consisting of a smart thermostat, a Heating, ventilation and air conditioning (HVAC) control unit, and a fan control unit.
11. The system of claim 1, wherein the operating reserve is operable to be sold to a utility.
12. The system of claim 1, wherein the system is operable to implement a flexible load-shape program operable to: project an operating reserve resulting from at least one selective disablement of the power flow from the electric power grid to the at least one power consuming device based on real-time preferences or preferences available within approximately less than 15 minutes of at least one customer; andproject power savings, the power savings being active, real-time, available within approximately less than 15 minutes, verifiable, and/or measurable.
13. The system of claim 1, wherein the actual value of power to be reduced is a power supply value (PSV); wherein the PSV is generated at a control center, a meter, a submeter, a building control system, or any device or controller that measures power within the standard as supplied by regulatory bodies that govern regulation of the electric power grid.
14. The system of claim 13, wherein the PSV is operable to determine a power consumption behavior and/or a commercial value for a response to a control event associated with the at least one power consuming device.
15. The system of claim 13, wherein the PSV is provided in units of monetary equivalent, and wherein the PSV indicates a compensation for providing supply equivalence to the electric power grid.
16. The system of claim 1, wherein the at least one controllable device is operable to: estimate an expected power consumption of the at least one power consuming device during an expected time period during which the flow of grid-supplied electric power to the at least one power consuming device is to be interrupted or reduced, based on the expected time period and a measured power consumption of the at least one power consuming device during at least one past time period;determine projected energy savings during the expected time period based on the estimated expected power consumption of the at least one power consuming device; anddetermine an operating reserve based on the projected energy savings, wherein the operating reserve is a regulating and/or spinning operating reserve.
17. The system of claim 1, further comprising a repository operable to store a measured power consumption of the at least one power consuming device during at least one past time period.
18. A system for managing power for an electric power grid, comprising: at least one active load client and at least one load controlled by the at least one active load client;wherein the at least one active load client is operable to receive at least one Internet Protocol (IP)-based power reduction message specifying an amount of electric power to be reduced for the at least one load;wherein the at least one active load client is further operable to automatically reduce the amount of power supplied to the at least one load in response to the at least one IP-based power reduction message;wherein an actual value of power reduced and/or to be reduced at each of the at least one load is calculated based on revenue grade metrology, and confirmed by measurement and verification;wherein the actual value of power reduced and/or to be reduced is a curtailment value as supply equivalence and provides operating reserve for the electric power grid;wherein the actual value of power reduced and/or to be reduced is provided in units of monetary equivalence indicating a compensation from utilities.
19. The system of claim 18, wherein the at least one active load client is operable to send a load status message to a utility control center, wherein the load status message includes at least one of a real time electric power usage, an actual amount of electric power reduced, and a type of the at least one load for which electric power was reduced.
20. The system of claim 18, wherein the at least one active load client is operable to store data relating to at least one time period during which power reduction is prohibited, wherein the at least one active load client is operable to maintain the amount of power supplied to the at least one load in response to the at least one IP-based power reduction message, and wherein the at least one IP-based power reduction message is received during the at least one time period during which power reduction is prohibited.

CROSS-REFERENCE TO RELATED APPLICATIONS

This application relates to and claims priority from the following U.S. Applications. This application is a continuation of U.S. application Ser. No. 14/517,399 filed Oct. 17, 2014 and issued as U.S. Pat. No. 9,651,973, which is a divisional of U.S. application Ser. No. 13/466,725 filed May 8, 2012 and issued as U.S. Pat. No. 8,890,505. U.S. application Ser. No. 13/466,725 is a continuation-in-part of U.S. application Ser. No. 13/019,867 filed Feb. 2, 2011 and issued as U.S. Pat. No. 8,996,183, is a continuation-in-part of U.S. application Ser. No. 12/775,979 filed May 7, 2010 and issued as U.S. Pat. No. 8,396,606, and is a continuation-in-part of U.S. application Ser. No. 12/001,819 filed Dec. 13, 2007 now abandoned. U.S. application Ser. No. 13/019,867 is a continuation-in-part of U.S. application Ser. No. 12/896,307 filed Oct. 1, 2010 and issued as U.S. Pat. No. 8,527,107, is a continuation-in-part of U.S. application Ser. No. 12/783,415 filed May 19, 2010 now abandoned, is a continuation-in-part of U.S. application Ser. No. 12/775,979 filed May 7, 2010 and issued as U.S. Pat. No. 8,396,606, is a continuation-in-part of U.S. application Ser. No. 12/715,195 filed Mar. 1, 2010 and issued as U.S. Pat. No. 8,032,233, is a continuation-in-part of U.S. application Ser. No. 12/715,124 filed Mar. 1, 2010 and issued as U.S. Pat. No. 8,010,812, is a continuation-in-part of U.S. application Ser. No. 12/001,819 filed Dec. 13, 2007 now abandoned. U.S. application Ser. No. 12/896,307 is a continuation-in-part of U.S. application Ser. No. 12/715,195 filed Mar. 1, 2010 and issued as U.S. Pat. No. 8,032,233, is a continuation-in-part of U.S. application Ser. No. 12/715,124 filed Mar. 1, 2010 and issued as U.S. Pat. No. 8,010,812, is a continuation-in-part of U.S. application Ser. No. 12/702,640 filed Feb. 9, 2010 and issued as U.S. Pat. No. 8,131,403. U.S. application Ser. No. 12/896,307 also claims priority from U.S. Provisional Application No. 61/279,072 filed Oct. 15, 2009. U.S. application Ser. No. 12/783,415 is a continuation-in-part of U.S. application Ser. No. 12/715,124 filed Mar. 1, 2010 and issued as U.S. Pat. No. 8,010,812. U.S. application Ser. No. 12/783,415 also claims priority from U.S. Provisional Application No. 61/216,712 filed May 20, 2009. U.S. application Ser. No. 12/775,979 is a continuation-in-part of U.S. application Ser. No. 12/001,819 filed Dec. 13, 2007 now abandoned, which is a continuation-in-part of U.S. application Ser. No. 11/895,909 filed on Aug. 28, 2007 and issued as U.S. Pat. No. 7,715,951. U.S. application Ser. No. 12/775,979 also claims the benefit of U.S. Provisional Application No. 61/215,725 filed May 8, 2009. U.S. application Ser. No. 12/715,195 is a division of U.S. application Ser. No. 11/895,909 filed Aug. 28, 2007 and issued as U.S. Pat. No. 7,717,951. U.S. application Ser. No. 12/715,124 is a division of U.S. application Ser. No. 11/895,909 filed Aug. 28, 2007 and issued as U.S. Pat. No. 7,717,951. U.S. application Ser. No. 12/702,640 is a continuation-in-part of U.S. application Ser. No. 11/895,909 filed Aug. 28, 2007 and issued as U.S. Pat. No. 7,717,951. U.S. application Ser. No. 12/702,640 also claims priority from U.S. Provisional Application No. 61/150,978 filed Feb. 9, 2009, and U.S. Provisional Application No. 61,176,752 filed May 8, 2009. U.S. application Ser. No. 12/001,819 is a continuation-in-part of U.S. application Ser. No. 11/895,909 filed Aug. 28, 2007 and issued as U.S. Pat. No. 7,717,951. Each of the above U.S. Applications is incorporated herein by reference in its entirety.

US Referenced Citations (371)

Number	Name	Date	Kind
3906242	Stevenson	Sep 1975	A
4023043	Stevenson	May 1977	A
4589075	Buennagel	May 1986	A
4799059	Grindahl et al.	Jan 1989	A
4819180	Hedman et al.	Apr 1989	A
4819229	Pritty et al.	Apr 1989	A
5237507	Chasek	Aug 1993	A
5361982	Liebl et al.	Nov 1994	A
5388101	Dinkins	Feb 1995	A
5462225	Massara et al.	Oct 1995	A
5481546	Dinkins	Jan 1996	A
5502339	Hartig	Mar 1996	A
5544036	Brown et al.	Aug 1996	A
5570002	Castleman	Oct 1996	A
5592491	Dinkins	Jan 1997	A
5640153	Hildebrand et al.	Jun 1997	A
5644173	Elliason et al.	Jul 1997	A
5675503	Moe et al.	Oct 1997	A
5696695	Ehlers et al.	Dec 1997	A
5721936	Kikinis et al.	Feb 1998	A
5926776	Glorioso et al.	Jul 1999	A
5973481	Thompson et al.	Oct 1999	A
6018690	Saito et al.	Jan 2000	A
6037758	Perez	Mar 2000	A
6078785	Bush	Jun 2000	A
6102487	Oevreboe	Aug 2000	A
6107693	Mongia et al.	Aug 2000	A
6115676	Rector et al.	Sep 2000	A
6154859	Norizuki et al.	Nov 2000	A
6216956	Ehlers et al.	Apr 2001	B1
6233327	Petite	May 2001	B1
6254009	Proffitt et al.	Jul 2001	B1
6304552	Chapman et al.	Oct 2001	B1
6366217	Cunningham et al.	Apr 2002	B1
6374101	Gelbien	Apr 2002	B1
6437692	Petite et al.	Aug 2002	B1
6519509	Nierlich et al.	Feb 2003	B1
6535797	Bowles et al.	Mar 2003	B1
6577962	Afshari	Jun 2003	B1
6583521	Lagod et al.	Jun 2003	B1
6601033	Sowinski	Jul 2003	B1
6602627	Liu et al.	Aug 2003	B2
6621179	Howard	Sep 2003	B1
6622097	Hunter	Sep 2003	B2
6622925	Carner et al.	Sep 2003	B2
6633823	Bartone et al.	Oct 2003	B2
6671586	Davis et al.	Dec 2003	B2
6681154	Nierlich et al.	Jan 2004	B2
6687574	Pietrowicz et al.	Feb 2004	B2
6718761	Merswolke et al.	Apr 2004	B2
6732055	Bagepalli et al.	May 2004	B2
6747368	Jarrett	Jun 2004	B2
6778882	Spool et al.	Aug 2004	B2
6784807	Petite et al.	Aug 2004	B2
6832135	Ying	Dec 2004	B2
6834811	Huberman et al.	Dec 2004	B1
6836737	Petite et al.	Dec 2004	B2
6862498	Davis et al.	Mar 2005	B2
6865450	Masticola et al.	Mar 2005	B2
6868293	Schurr et al.	Mar 2005	B1
6879059	Sleva	Apr 2005	B2
6891838	Petite et al.	May 2005	B1
6904336	Raines et al.	Jun 2005	B2
6906617	Van der Meulen	Jun 2005	B1
6909942	Andarawis et al.	Jun 2005	B2
6914533	Petite	Jul 2005	B2
6914893	Petite	Jul 2005	B2
6934316	Cornwall et al.	Aug 2005	B2
6961641	Forth et al.	Nov 2005	B1
6990593	Nakagawa	Jan 2006	B2
7003640	Mayo et al.	Feb 2006	B2
7019667	Petite et al.	Mar 2006	B2
7035719	Howard et al.	Apr 2006	B2
7039532	Hunter	May 2006	B2
7053767	Petite et al.	May 2006	B2
7088014	Nierlich et al.	Aug 2006	B2
7103511	Petite	Sep 2006	B2
7123994	Weik et al.	Oct 2006	B2
7133750	Raines et al.	Nov 2006	B2
7136725	Paciorek et al.	Nov 2006	B1
7141321	McArthur et al.	Nov 2006	B2
7142949	Brewster et al.	Nov 2006	B2
7177728	Gardner	Feb 2007	B2
7181320	Whiffen et al.	Feb 2007	B2
7184861	Petite	Feb 2007	B2
7200134	Proctor et al.	Apr 2007	B2
7206670	Pimputkar et al.	Apr 2007	B2
7209804	Curt et al.	Apr 2007	B2
7209840	Petite et al.	Apr 2007	B2
7233843	Budhraja et al.	Jun 2007	B2
7263073	Petite et al.	Aug 2007	B2
7274975	Miller	Sep 2007	B2
7289887	Rodgers	Oct 2007	B2
7295128	Petite	Nov 2007	B2
7305282	Chen	Dec 2007	B2
7313465	O'Donnell	Dec 2007	B1
7343341	Sandor et al.	Mar 2008	B2
7345998	Cregg et al.	Mar 2008	B2
7346463	Petite et al.	Mar 2008	B2
7366164	Habib et al.	Apr 2008	B1
7397907	Petite	Jul 2008	B2
7406364	Rissanen et al.	Jul 2008	B2
7412304	Uenou	Aug 2008	B2
7424527	Petite	Sep 2008	B2
7440871	McConnell et al.	Oct 2008	B2
7451019	Rodgers	Nov 2008	B2
7468661	Petite et al.	Dec 2008	B2
7480501	Petite	Jan 2009	B2
7486681	Weber	Feb 2009	B2
7492617	Petter et al.	Feb 2009	B2
7528503	Rognli et al.	May 2009	B2
7536240	McIntyre et al.	May 2009	B2
7541941	Bogolea et al.	Jun 2009	B2
7565227	Richard et al.	Jul 2009	B2
7650425	Davis et al.	Jan 2010	B2
7697492	Petite	Apr 2010	B2
7711796	Gutt et al.	May 2010	B2
7715951	Forbes et al.	May 2010	B2
7738999	Petite	Jun 2010	B2
7739378	Petite	Jun 2010	B2
8010812	Forbes et al.	Aug 2011	B2
8032233	Forbes, Jr. et al.	Oct 2011	B2
8046110	Mayor et al.	Oct 2011	B2
8131403	Forbes et al.	Mar 2012	B2
8145361	Forbes, Jr. et al.	Mar 2012	B2
8260470	Forbes, Jr. et al.	Sep 2012	B2
8295989	Rettger et al.	Oct 2012	B2
8307225	Forbes, Jr. et al.	Nov 2012	B2
8315717	Forbes, Jr. et al.	Nov 2012	B2
8359124	Zhou et al.	Jan 2013	B2
8364609	Ozog	Jan 2013	B2
8396606	Forbes et al.	Mar 2013	B2
8417569	Gross	Apr 2013	B2
8457802	Steven et al.	Jun 2013	B1
8463449	Sanders	Jun 2013	B2
8473111	Shankar et al.	Jun 2013	B1
8527107	Forbes et al.	Sep 2013	B2
8570999	Nguyen	Oct 2013	B1
8571930	Galperin	Oct 2013	B1
8583520	Forbes	Nov 2013	B1
8588991	Forbes, Jr.	Nov 2013	B1
8761952	Forbes	Jun 2014	B2
8890505	Forbes	Nov 2014	B2
8983669	Forbes, Jr.	Mar 2015	B2
8996183	Forbes	Mar 2015	B2
9177323	Forbes	Nov 2015	B2
9461471	Forbes, Jr.	Oct 2016	B2
9651973	Forbes, Jr.	May 2017	B2
9952611	Forbes, Jr.	Apr 2018	B2
9989982	Forbes, Jr.	Jun 2018	B2
20010030468	Anderson et al.	Oct 2001	A1
20010038343	Meyer et al.	Nov 2001	A1
20020019758	Scarpelli	Feb 2002	A1
20020019802	Malme et al.	Feb 2002	A1
20020035496	Fukushima et al.	Mar 2002	A1
20020036430	Welches et al.	Mar 2002	A1
20020109607	Cumeralto et al.	Aug 2002	A1
20020138176	Davis et al.	Sep 2002	A1
20020143693	Soestbergen et al.	Oct 2002	A1
20020161648	Mason et al.	Oct 2002	A1
20020198629	Ellis	Dec 2002	A1
20030009401	Ellis	Jan 2003	A1
20030009705	Thelander et al.	Jan 2003	A1
20030036820	Yellepeddy et al.	Feb 2003	A1
20030083980	Satake	May 2003	A1
20030144864	Mazzarella	Jul 2003	A1
20030149937	Mcelfresh et al.	Aug 2003	A1
20030158632	Nierlich et al.	Aug 2003	A1
20030176952	Collins et al.	Sep 2003	A1
20030225483	Santinato et al.	Dec 2003	A1
20030229572	Raines et al.	Dec 2003	A1
20030233201	Horst et al.	Dec 2003	A1
20040006439	Hunter	Jan 2004	A1
20040024483	Holcombe	Feb 2004	A1
20040044571	Bronnimann et al.	Mar 2004	A1
20040088083	Davis et al.	May 2004	A1
20040107025	Ransom	Jun 2004	A1
20040117330	Ehlers et al.	Jun 2004	A1
20040128266	Yellepeddy et al.	Jul 2004	A1
20040153170	Santacatterina et al.	Aug 2004	A1
20040158478	Zimmerman	Aug 2004	A1
20040158541	Notarianni et al.	Aug 2004	A1
20040162793	Scott et al.	Aug 2004	A1
20040193329	Ransom et al.	Sep 2004	A1
20040225514	Greenshields et al.	Nov 2004	A1
20040230533	Benco	Nov 2004	A1
20050021397	Cui et al.	Jan 2005	A1
20050033481	Budhraja et al.	Feb 2005	A1
20050055432	Rodgers	Mar 2005	A1
20050065742	Rodgers	Mar 2005	A1
20050080772	Bem	Apr 2005	A1
20050096856	Lubkeman et al.	May 2005	A1
20050096857	Hunter	May 2005	A1
20050096979	Koningstein	May 2005	A1
20050097204	Horowitz et al.	May 2005	A1
20050125243	Villalobos	Jun 2005	A1
20050127680	Lof et al.	Jun 2005	A1
20050138432	Ransom	Jun 2005	A1
20050192711	Raines et al.	Sep 2005	A1
20050192713	Weik et al.	Sep 2005	A1
20050216302	Raji et al.	Sep 2005	A1
20050216580	Raji et al.	Sep 2005	A1
20050234600	Boucher et al.	Oct 2005	A1
20050240314	Martinez	Oct 2005	A1
20050240315	Booth et al.	Oct 2005	A1
20050246190	Sandor et al.	Nov 2005	A1
20050267642	Whiffen et al.	Dec 2005	A1
20050276222	Kumar et al.	Dec 2005	A1
20050288954	Mccarthy et al.	Dec 2005	A1
20060020544	Kaveski	Jan 2006	A1
20060020596	Liu et al.	Jan 2006	A1
20060022841	Hoiness et al.	Feb 2006	A1
20060025891	Budike	Feb 2006	A1
20060031934	Kriegel	Feb 2006	A1
20060064205	Ying	Mar 2006	A1
20060069616	Bau	Mar 2006	A1
20060106635	Ulrich et al.	May 2006	A1
20060142900	Rothman et al.	Jun 2006	A1
20060142961	Johnson et al.	Jun 2006	A1
20060161450	Carey et al.	Jul 2006	A1
20060168191	Ives	Jul 2006	A1
20060190354	Meisel et al.	Aug 2006	A1
20060195334	Reeb et al.	Aug 2006	A1
20060212350	Ellis et al.	Sep 2006	A1
20060224615	Korn et al.	Oct 2006	A1
20060241244	Soeda et al.	Oct 2006	A1
20060241314	Sullivan et al.	Oct 2006	A1
20060271244	Cumming et al.	Nov 2006	A1
20060271314	Hayes	Nov 2006	A1
20060276938	Miller	Dec 2006	A1
20060282328	Gerace et al.	Dec 2006	A1
20070021874	Rognli et al.	Jan 2007	A1
20070038563	Ryzerski	Feb 2007	A1
20070058453	Shaffer et al.	Mar 2007	A1
20070058629	Luft	Mar 2007	A1
20070070895	Narvaez	Mar 2007	A1
20070085702	Walters et al.	Apr 2007	A1
20070091900	Asthana et al.	Apr 2007	A1
20070094043	Bannai et al.	Apr 2007	A1
20070100503	Balan et al.	May 2007	A1
20070100961	Moore	May 2007	A1
20070150353	Krassner et al.	Jun 2007	A1
20070156621	Wright et al.	Jul 2007	A1
20070156887	Wright et al.	Jul 2007	A1
20070174114	Bigby et al.	Jul 2007	A1
20070192333	Ali	Aug 2007	A1
20070203722	Richards et al.	Aug 2007	A1
20070204176	Shaffer et al.	Aug 2007	A1
20070213878	Chen	Sep 2007	A1
20070214118	Schoen et al.	Sep 2007	A1
20070214132	Grubb et al.	Sep 2007	A1
20070255457	Whitcomb et al.	Nov 2007	A1
20070260540	Chau et al.	Nov 2007	A1
20070282495	Kempton et al.	Dec 2007	A1
20070286210	Gutt et al.	Dec 2007	A1
20070291644	Roberts et al.	Dec 2007	A1
20070299562	Kates	Dec 2007	A1
20080010212	Moore et al.	Jan 2008	A1
20080015976	Sandor et al.	Jan 2008	A1
20080040223	Bridges et al.	Feb 2008	A1
20080091625	Kremen	Apr 2008	A1
20080104026	Koran	May 2008	A1
20080109387	Deaver et al.	May 2008	A1
20080130673	Cregg et al.	Jun 2008	A1
20080147465	Raines et al.	Jun 2008	A1
20080154801	Fein et al.	Jun 2008	A1
20080165714	Dettinger et al.	Jul 2008	A1
20080172312	Synesiou et al.	Jul 2008	A1
20080177423	Brickfield et al.	Jul 2008	A1
20080177678	Di Martini	Jul 2008	A1
20080195462	Magdon-Ismail et al.	Aug 2008	A1
20080224892	Bogolea et al.	Sep 2008	A1
20080231114	Tolnar et al.	Sep 2008	A1
20080238710	Tolnar et al.	Oct 2008	A1
20080249832	Richardson et al.	Oct 2008	A1
20080255899	McConnell et al.	Oct 2008	A1
20080263025	Koran	Oct 2008	A1
20080270223	Collins et al.	Oct 2008	A1
20080281473	Pitt	Nov 2008	A1
20080306824	Parkinson	Dec 2008	A1
20080306830	Lasa et al.	Dec 2008	A1
20080319893	Mashinsky et al.	Dec 2008	A1
20090012996	Gupta et al.	Jan 2009	A1
20090018884	McConnell et al.	Jan 2009	A1
20090024718	Anagnostopoulos et al.	Jan 2009	A1
20090043519	Bridges et al.	Feb 2009	A1
20090043520	Pollack et al.	Feb 2009	A1
20090045804	Durling et al.	Feb 2009	A1
20090055031	Slota et al.	Feb 2009	A1
20090062970	Forbes et al.	Mar 2009	A1
20090063228	Forbes	Mar 2009	A1
20090088907	Lewis et al.	Apr 2009	A1
20090112701	Turpin et al.	Apr 2009	A1
20090112758	Herzig	Apr 2009	A1
20090124241	Krishnaswamy et al.	May 2009	A1
20090125462	Krishnaswamy et al.	May 2009	A1
20090135836	Veillette	May 2009	A1
20090138362	Schroedl et al.	May 2009	A1
20090187344	Brancaccio et al.	Jul 2009	A1
20090187499	Mulder et al.	Jul 2009	A1
20090198384	Ahn	Aug 2009	A1
20090228335	Niyogi et al.	Sep 2009	A1
20090240381	Lane	Sep 2009	A1
20090240677	Parekh et al.	Sep 2009	A1
20090281673	Taft	Nov 2009	A1
20090281674	Taft	Nov 2009	A1
20090319415	Stoilov et al.	Dec 2009	A1
20100076835	Silverman	Mar 2010	A1
20100082464	Keefe	Apr 2010	A1
20100106575	Bixby	Apr 2010	A1
20100106641	Chassin et al.	Apr 2010	A1
20100138452	Henkin et al.	Jun 2010	A1
20100169175	Koran	Jul 2010	A1
20100191862	Forbes et al.	Jul 2010	A1
20100217452	Mccord et al.	Aug 2010	A1
20100217549	Galvin et al.	Aug 2010	A1
20100217550	Crabtree et al.	Aug 2010	A1
20100217642	Crubtree et al.	Aug 2010	A1
20100218108	Crabtree et al.	Aug 2010	A1
20100222935	Forbes, Jr.	Sep 2010	A1
20100235008	Forbes, Jr.	Sep 2010	A1
20100274407	Creed	Oct 2010	A1
20100293045	Burns et al.	Nov 2010	A1
20100306033	Oved et al.	Dec 2010	A1
20100332373	Crabtree et al.	Dec 2010	A1
20110025556	Bridges et al.	Feb 2011	A1
20110055036	Helfan	Mar 2011	A1
20110060474	Schmiegel et al.	Mar 2011	A1
20110080044	Schmiegel	Apr 2011	A1
20110106729	Billingsley et al.	May 2011	A1
20110115302	Slota et al.	May 2011	A1
20110133655	Recker et al.	Jun 2011	A1
20110145061	Spurr et al.	Jun 2011	A1
20110147360	Hammerstrom	Jun 2011	A1
20110161250	Koeppel et al.	Jun 2011	A1
20110172841	Forbes	Jul 2011	A1
20110178610	Gamble et al.	Jul 2011	A1
20110185303	Katagi et al.	Jul 2011	A1
20110196546	Muller et al.	Aug 2011	A1
20110204717	Shaffer	Aug 2011	A1
20110208366	Taft	Aug 2011	A1
20110235656	Pigeon	Sep 2011	A1
20110251730	Pitt	Oct 2011	A1
20110257809	Forbes et al.	Oct 2011	A1
20110258022	Forbes, Jr. et al.	Oct 2011	A1
20110270452	Lu et al.	Nov 2011	A1
20120029897	Cherian et al.	Feb 2012	A1
20120196482	Stokoe	Aug 2012	A1
20120205977	Shin et al.	Aug 2012	A1
20120221162	Forbes	Aug 2012	A1
20120223840	Guymon et al.	Sep 2012	A1
20120226384	Forbes	Sep 2012	A1
20120232816	Oh et al.	Sep 2012	A1
20120239218	Forbes	Sep 2012	A1
20120239219	Forbes	Sep 2012	A1
20120245753	Forbes	Sep 2012	A1
20120259760	Sgouridis et al.	Oct 2012	A1
20120296799	Playfair et al.	Nov 2012	A1
20120316697	Boardman et al.	Dec 2012	A1
20130035802	Khaitan et al.	Feb 2013	A1
20130036311	Akyol et al.	Feb 2013	A1
20130079939	Darden, II et al.	Mar 2013	A1
20130079943	Darden, II et al.	Mar 2013	A1
20130090935	Uselton	Apr 2013	A1
20130144768	Rohrbaugh	Jun 2013	A1
20140018969	Forbes	Jan 2014	A1
20140025486	Bigby et al.	Jan 2014	A1
20140039699	Forbes	Feb 2014	A1
20140039701	Forbes	Feb 2014	A1
20140039703	Forbes	Feb 2014	A1
20150303691	Forbes	Oct 2015	A1

Foreign Referenced Citations (15)

Number	Date	Country
1729223	Dec 2006	EP
2000078748	Mar 2000	JP
2001306839	Nov 2001	JP
2004180412	Jun 2004	JP
2004248174	Sep 2004	JP
2006060911	Mar 2006	JP
2007132553	May 2007	JP
20050045272	May 2005	KR
20060036171	Apr 2006	KR
20070008321	Jan 2007	KR
100701298	Mar 2007	KR
20070098172	Oct 2007	KR
20080112692	Dec 2008	KR
2007136456	Nov 2007	WO
2008125696	Oct 2008	WO

Non-Patent Literature Citations (19)

Entry
B.J. Kirby, Spinning Reserve from Responsive Loads, Oak Ridge National Laboratory, United States Dept. of Energy, Mar. 2003 (54 pages).
Byers J. Risk Management and Monetizing the Commodity Storage Option. Natural Gas & Electricity [serial online]. Jul. 2005; 21 (12):1-8. Available from: Business Source Complete, Ipswich, MA.
C.W. Gellings and W.M. Smith, Integrating Demand-Side Management into Utility Planning, Proceedings of the IEEE, vol. 77, Issue: 6, Jun. 1989, pp. 908-918 (Abstract only).
Eric Hirst and Brendan Kirby, Opportunities for Demand Participation in New England Contingency-Reserve Markets, New England Demand Response Initiative, Feb. 2003 (15 pages).
Eric Hirst and Richard Cowart, Demand Side Resources and Reliability, New England Demand Response Initiative, Mar. 20, 2002 (32 pages).
Galvin Electricity Institute: Frequently Asked Questions, printed Apr. 23, 2014, same page available through archive.org unchanged Mar. 1, 2008.
GE Digital Energy Residential Electrical Metering Brochure. Sep. 12, 2012. https://web.archive.org/web/20120912144353/http://www.gedigitalenergry.com/products/brochures/1210-Family.pdf.
Illinois General Assembly: Public Act 094-0977, Effective Date: Jun. 30, 2006.
Kamat R., Oren S. Two-Settlement Systems for Electricity Markets under Network Uncertainty and Market Power Journal of Regulatory Economics [serial online]. Jan. 2004; 25(1):5-37.
Kathleen Spees and Lester B. Lave, Demand Response and Electricity Market Efficiency, The Electricity Journal, vol. 20, Issue 3, Apr. 2007 (online Mar. 27, 2007), pp. 69-85 (Abstract only).
L.T. Anstine, R.E. Burke, J.E. Casey, R. Holgate, R.S. John, and H.G. Stewart, Application of Probability Methods to the Determination of Spinning Reserve Requirements for the Pennsylvania-New Jersey-Maryland Interconnection; IEEE Transactions on Power Apparatus and Systems, vol. 82, Issue 68, Oct. 1963, pp. 726-735 (Abstract only).
Lobsenz G. Maryland Regulators Reject BG&E Smart Grid Proposal. Energy Daily [serial online]. Jun. 23, 2010; (118):3. Available from: Business Source Complete, Ipswich, MA.
M. Rashidi-Nejad, Y.H. Song, and M.H. Javidi-Dasht-Bayaz, Operating Reserve Provision in Deregulated Power Markets, IEEE Power Engineering Society Winter Meeting, vol. 2, 2002, pp. 1305-1310 (Abstract only).
Michael Ahlheim and Friedrich Schneider; “Allowing for Household Preferences in Emission Trading, A Contribution to the Climate Policy Debate”; Environmental and Resource Economics, vol. 21, pp. 317-342; Kluwer Academic Jublishers; The Netherlands; 2002.
Olivier Rousse; “Environmental and economic benefits resulting from citizens' participation in CO.sub.2 emissions trading: An efficient alternative solution to the voluntary compensation of CO.sub.2 emissions”, Energy Policy 36 (2008), pp. 388-397; Oct. 29, 2007 (online).
Pablo A. Ruiz and Peter W. Sauer, Valuation of Reserve Services, IEEE Proceedings of the 41 .sup.st Hawaii International Conference on System Sciences, 2008 (9 pages).
Paul Darbee, Insteon Compared, SmartLabs, Inc., Jan. 2, 2006, 69 pages.
Paul Darbee, Insteon The Details, Smarthome, Inc., Aug. 11, 2005, 68 pages.
Zhu Jinxiang, G. Jordan, and S. Ihara, The Market for Spinning Reserve and Its Impacts on Energy Prices, IEEE Power Engineering Society Winter Meeting, vol. 2, 2000, pp. 1202-1207 (Abstract Only).

Related Publications (1)

	Number	Date	Country
	20170250567 A1	Aug 2017	US

Provisional Applications (5)

Number	Date	Country
61215725	May 2009	US
61216712	May 2009	US
61279072	Oct 2009	US
61176752	May 2009	US
61150978	Feb 2009	US

Divisions (3)

	Number	Date	Country
Parent	13466725	May 2012	US
Child	14517399		US
Parent	11895909	Aug 2007	US
Child	12715124		US
Parent	11895909	Aug 2007	US
Child	12715195		US

Continuations (1)

	Number	Date	Country
Parent	14517399	Oct 2014	US
Child	15594219		US

Continuation in Parts (16)

	Number	Date	Country
Parent	13019867	Feb 2011	US
Child	13466725		US
Parent	12775979	May 2010	US
Child	13019867		US
Parent	12001819	Dec 2007	US
Child	12775979		US
Parent	11895909	Aug 2007	US
Child	12001819		US
Parent	12783415	May 2010	US
Child	13019867	Feb 2011	US
Parent	12001819	Dec 2007	US
Child	12783415		US
Parent	12715124	Mar 2010	US
Child	12001819		US
Parent	12896307	Oct 2010	US
Child	13019867	Feb 2011	US
Parent	12715124	Mar 2010	US
Child	12896307		US
Parent	12715195	Mar 2010	US
Child	12715124		US
Parent	12702640	Feb 2010	US
Child	12896307	Oct 2010	US
Parent	11895909	Aug 2007	US
Child	12702640		US
Parent	12715124	Mar 2010	US
Child	13019867	Feb 2011	US
Parent	12715195	Mar 2010	US
Child	12715124		US
Parent	12001819	Dec 2007	US
Child	13466725	May 2012	US
Parent	12001819	Dec 2007	US
Child	13019867	Feb 2011	US

System and method for estimating and providing dispatchable operating reserve energy capacity through use of active load management

Information

Patent Number

Date Filed

Date Issued

Inventors

Original Assignees

Examiners

Agents

CPC

Field of Search

US

International Classifications

Disclaimer

Term Extension

Abstract