CA3036431A1 - Method and system for establishing in real-time an energy clearing price for microgrids having distributed energy resources - Google Patents
Method and system for establishing in real-time an energy clearing price for microgrids having distributed energy resources Download PDFInfo
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- H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
- H02J—ELECTRIC POWER NETWORKS; CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
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- H02J13/13—Circuit arrangements for providing remote monitoring or remote control of equipment in a power distribution network characterised by the transmission of data to equipment in the power network
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- H02J13/00—Circuit arrangements for providing remote monitoring or remote control of equipment in a power distribution network
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Abstract
A method for establishing an energy clearing price for electrical energy within a microgrid is provided. The method comprising receiving, at a microgrid market management ("MMM") system, a price for electrical energy delivered to the microgrid from a transmission/distribution system or the transmission/distribution system from the microgrid; monitoring electric power flow between a first and a second prosumer systems and the microgrid using respective first and second prosumer meters located at respective locations of said first and second prosumer systems within the microgrid; monitoring electric power flow between the microgrid and the transmission/distribution system using a meter located at a point of common coupling ("PCC") between the microgrid and the transmission/distribution system; and determining, at the MMM, the energy clearing price from the price for electrical energy delivered to the microgrid from the transmission/distribution system or the transmission/distribution system from the microgrid; the respective locations of the first and second prosumer systems within the microgrid; and, the electric power flow between the first and second prosumer systems and the microgrid.
Description
METHOD AND SYSTEM FOR ESTABLISHING IN REAL-TIME AN ENERGY
CLEARING PRICE FOR MICROGRIDS HAVING DISTRIBUTED ENERGY RESOURCES
[0001] This application claims priority from and the benefit of the filing date of United States Provisional Patent Application No. 62/393,740, filed September 13, 2016, and the entire content of such application is incorporated herein by reference.
FIELD OF THE APPLICATION
CLEARING PRICE FOR MICROGRIDS HAVING DISTRIBUTED ENERGY RESOURCES
[0001] This application claims priority from and the benefit of the filing date of United States Provisional Patent Application No. 62/393,740, filed September 13, 2016, and the entire content of such application is incorporated herein by reference.
FIELD OF THE APPLICATION
[0002] This application relates to the field of market management for power distribution systems, and more specifically, to a method and system for real-time market management for microgrids having distributed energy resources.
BACKGROUND OF THE APPLICATION
BACKGROUND OF THE APPLICATION
[0003] In electric power distribution grids where so called net metering arrangements are not used, have been changed (e.g., reduced), or have been cancelled, economic incentives for distributed energy resource ("DER") deployment are diminished. DERs may include solar photovoltaic ("PV") power plants, wind power plants, and power storage (e.g., battery, etc.) plants. This creates .. opportunities for energy exchange between energy users and DER operators increasing their energy cost savings and/or generation revenue streams. This energy exchange may be facilitated by developing energy markets in distribution grid segments that make this exchange financially efficient. These local or micro-markets may also be more technically efficient as they reduce energy losses in transmission and distribution systems.
[0004] Net metering (or net energy metering) ("NEM") allows consumers who generate some or all of their own electric power to sell excess electric power into the distribution grid at times when it is not needed and consume electric power from the grid when required. This is particularly important with electric power generated by wind and solar energy. Electric power exchange with the grid in net metering arrangements is executed at the same retail price defined by the utility service provider, and consumers pay or are billed only for the difference between the electric power generated and consumed over a billing period. Thus, in net metering arrangements, the distribution grid provides consumers with a form of free electricity storage service while consumers provide the grid with all available electric power generating resources to meet power demands.
[0005] However, with the growing penetration of DERs in the distribution grid, the operating costs of utilities maintaining standard operating conditions in the grid, such as voltage and frequency, may exceed the benefits of having access to electric power resources from DER
operators/consumers having DERs. This has resulted in the cancelling of net metering arrangements by a number of utilities and an evolving trend to limit or remove these arrangements from electricity retail practice.
Such developments have been referred to as the "end of net metering".
operators/consumers having DERs. This has resulted in the cancelling of net metering arrangements by a number of utilities and an evolving trend to limit or remove these arrangements from electricity retail practice.
Such developments have been referred to as the "end of net metering".
[0006] This limitation, change, and/or cancellation of net metering arrangements has created a new market situation in distribution grids and segments thereof equipped with advanced energy management tools. These tools enable consumers with power generation capacity to sell the excess generated power to other consumers/market participants within their grid segment or into other grid segments of the distribution grid. These activities have created new energy market opportunities for electric power exchange and sale.
[0007] FIG. 1 is a block diagram illustrating a microgrid in accordance with the prior art (see Eger, et al., "Microgrid Scenario Building Blocks", FI.ICT-2011-285135, FINSENY, D.3.1 v1.0, 2011, which is incorporated herein by reference). Existing microgrids and their functionality are described in the following. With the growing penetration of DERs, the technical and commercial value of grid segments enabled with advanced management and control of DERs has increased.
These grid segments that are now referred to as microgrids. A "microgrid" 100 may be defined as a low-voltage ("LV") or medium-voltage ("MV") distribution system having distributed energy resources (e.g., micro turbines, fuel cells, photovoltaic ("PV") power generators, etc.) and storage devices (e.g., flywheels, energy capacitors, batteries, etc.) for satisfying the demands of energy consumers, the energy consumers being connected to the same distribution system (i.e., they are microgrid consumers). The microgrid itself is connected to the grid.
These grid segments that are now referred to as microgrids. A "microgrid" 100 may be defined as a low-voltage ("LV") or medium-voltage ("MV") distribution system having distributed energy resources (e.g., micro turbines, fuel cells, photovoltaic ("PV") power generators, etc.) and storage devices (e.g., flywheels, energy capacitors, batteries, etc.) for satisfying the demands of energy consumers, the energy consumers being connected to the same distribution system (i.e., they are microgrid consumers). The microgrid itself is connected to the grid.
[0008] The difference between a microgrid and a passive grid segment penetrated by micro-sources lies mainly in the manner in which the available resources are managed and coordinated. Microgrids may be operated in a semiautonomous way, if connected to the grid, or in an autonomous way (i.e., islanding mode), if disconnected from the grid. Microgrids also allow for the aggregation of DERs and electrical loads and may operate as virtual power plants ("VPPs").
[0009] Microgrids allow for several advanced energy management and control use cases including:
balancing supply and demand on different time-scales; demand-side management;
supply-side management; storage management; islanding mode management including black start in islanding mode; protection & restoration; smart metering; auto-configuration; and, planning.
.. [0010] In more detail, the main actors with respect to the operation of a microgrid include: a microgrid operator who handles the system operator, energy retailer, and aggregator roles in a traditional grid model; an overlay grid operator who is the operator of the grid to which the microgrid has a connection point; a prosumer who is a consumer, DER (e.g., PV, wind, and/or storage plant) owner, and/or storage owner; and, a service provider who provides weather forecasts, energy market analysis, etc.
[0011] With respect to microgrids and electric power trading, a microgrid also provides an open trading and communication platform for all internal and external trading. The types of markets defined in the existing literature are as follows: the general wholesale market comprising the main energy market for general national and international trading and the spot energy market for short-.. term trading; the balancing market for rebalancing supply and demand in the case of upcoming power shortages; the market for ancillary services to provide additional services like frequency control, voltage support, etc.; and, the future (regional) retail market. The retail market provides a "gate" for microgrid electric power and service trading to external markets.
It is assumed that all microgrid prosumers having a contract with the microgrid operator ("MO") and trust that the MO
will represent all of the MO's customers towards the external markets and will distribute the internal resources to the MO's customers in the best way respecting internal energy generation and consumption.
[0012] In the existing literature with respect to microgrid arrangements, it is assumed that the MO
provides the following market services: sells/buys energy on the external market; and, sells balancing and ancillary services. (See Sai Krovvidi, "Competitive Microgrid Electricity Market Design", Master of Science in Electrical Engineering Thesis, Virginia Polytechnic Institute and State University, Arlington, Virginia, 2010, which is incorporated herein by reference.) [0013] With respect to the electricity markets and market management, the following is an overview of the wholesale market and the retail market. According to the literature (see Ignacio J. Perez-Arriaga, "Engineering, Economics & Regulation of the Electric Power System", MIT, 2010, which is incorporated herein by reference), typical wholesale market products and services include the following: scheduled energy (in long-term contracts, day-ahead, intra-day and/or balancing markets);
frequency control - primary reserve, secondary reserve, tertiary reserve;
reactive power for voltage regulation; black-start capabilities; and, generation capacity for long term adequacy. Electricity prices in wholesale markets are established as follows: ISO/RTOs use a uniform (or single) clearing price auction in which electricity generators place bids with an independent market administrator for a particular time period; the independent administrator then dispatches the generators from lowest to highest bids until all power demand is met; and, each generator that is dispatched is then paid the same price as what was paid for the last unit of electric power needed to meet total demand.
[0014] With respect to the retail market, in states where full retail competition (often called "retail choice") is provided, customers may choose between their incumbent utility supplier and an array of competitive suppliers, as opposed to being a captive customer to a single provider. Competitive retail suppliers provide a variety of service plans that give consumers and businesses flexibility in their energy purchases. They may also offer services to hedge against price fluctuations, more choices for alternative energy resources, and newer energy efficiency projects, among others. These opportunities allow consumers and businesses to choose the services that best meet their needs. In retail choice states, commissions approve any alternative competitive supplier before they can serve customers. The commissions also oversee power procurement and approve the results of the process and whether the process was fair. In states not offering retail competition, the commissions regulate the expenditures of the monopoly utilities by allowing a rate of return on most costs. In these states, utilities are vertically-integrated and may construct, own, and operate power plants - at the ratepayers' expense.
[0015] However, there are several problems with the operation of existing microgrids. For example, one problem with existing microgrid electricity trading platforms and existing electricity markets is that existing solutions are focused on day ahead energy markets (e.g., day ahead scheduling of intermittent resources) and as such they do not address real-time market management needs. As another example, existing microgrids lack energy management and control solutions for real-time internal microgrid market ("micromarker) management.
[0016] A need therefore exists for an improved method and system for real-time market management for microgrids having distributed energy resources. Accordingly, a solution that addresses, at least in part, the above and other shortcomings is desired.
SUMMARY OF THE APPLICATION
[0017] According to one aspect of the application, there is provided a method for managing a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, the method comprising: using a microgrid market management ("MMM") system: establishing an energy clearing price for electrical energy within the microgrid; settling energy transactions between the first and second prosumer systems within the microsystem; aggregating distributed energy resources and controllable loads of the first and second prosumer systems within the microgrid and transmitting a bid for the aggregated distributed energy resources and controllable loads to one or more of a wholesale energy market system, an ancillary services market system, and a utility system; and, controlling the distributed energy resources and controllable loads upon receipt of control signals from one or more of the .. wholesale energy market system, the ancillary services market system, and the utility system.
[0018] According to another aspect of the application, there is provided a method for establishing an energy clearing price for electrical energy within a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, the method comprising: using a microgrid market management ("MMM") system: receiving a price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid;
monitoring electric power flow between the first and second prosumer systems and the microgrid using respective first and second prosumer meters, the first and second prosumer meters located at respective locations of the first and second prosumer systems within the microgrid; monitoring electric power flow between the microgrid and the transmission/distribution system using a meter located at a point of common coupling between the microgrid and the transmission/distribution system; and, using a processor within the MMM system, determining the energy clearing price from: the price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid; the respective locations of the first and second prosumer systems within the microgrid; and, the electric power flow between the first and second prosumer systems and the microgrid.
[0019] In accordance with further aspects of the application, there is provided an apparatus such as a data processing system, a microgrid market management system, a prosumer system, a control system, a forecasting system, etc., a method for adapting same, as well as articles of manufacture such as a computer readable medium or product and computer program product or software product (e.g., comprising a non-transitory medium) having program instructions recorded thereon for practising the method of the application.
BRIEF DESCRIPTION OF THE DRAWINGS
[0020] Further features and advantages of the embodiments of the present application will become apparent from the following detailed description, taken in combination with the appended drawings, in which:
[0021] FIG. 1 is a block diagram illustrating a microgrid in accordance with the prior art;
[0022] FIG. 2 is a block diagram illustrating energy flows for ex-post market and settlement prices for a microgrid as determined by a microgrid market management system in accordance with an embodiment of the application;
[0023] FIG. 3 is a block diagram illustrating ex-ante market and settlement prices for a microgrid as determined by a microgrid market management system in accordance with an embodiment of the application;
[0024] FIG. 4 is a block diagram illustrating frequency control aggregation by a microgrid market management system for a microgrid in accordance with an embodiment of the application;
[0025] FIG. 5 is a block diagram illustrating real-time energy market participation for a microgrid as implemented by a microgrid market management system in accordance with an embodiment of the application;
[0026] FIG. 6 is a block diagram illustrating a data processing system in accordance with an embodiment of the application; and, [0027] FIG. 7 is a flow chart illustrating operations of modules within a data processing system for managing a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, in accordance with an embodiment of the application.
[0028] It will be noted that throughout the appended drawings, like features are identified by like reference numerals.
DETAILED DESCRIPTION OF THE EXAMPLE EMBODIMENTS
[0029] In the following description, details are set forth to provide an understanding of the application. In some instances, certain software, circuits, structures and methods have not been described or shown in detail in order not to obscure the application. The term "data processing system" or "system" is used herein to refer to any machine for processing data, including the computer systems, MMM systems, prosumer systems, control systems, forecasting systems, and network arrangements described herein. The present application may be implemented in any computer programming language provided that the operating system of the data processing system provides the facilities that may support the requirements of the present application. Any limitations presented would be a result of a particular type of operating system or computer programming language and would not be a limitation of the present application. The present application may also be implemented in hardware or in a combination of hardware and software.
[0030] According to one aspect of the application, there is provided a method and system for real-time microgrid market management ("MMM") enabling internal trade within a microgrid as well as external trading with other microgrids and/or with the main distribution grid through the microgrid's open trading and communication platform. The microgrid market management method and system of the present application allows a market participant to sell excess energy to other market participants rather than to a utility allowing for a selling price that may be higher than an excess energy credit and a purchase price that may be lower than a volumetric charge.
[0031] FIG. 6 is a block diagram illustrating a data processing system 300 in accordance with an embodiment of the invention. The data processing 300 is suitable for performing as a microgrid market management ("MMM") system 500, a prosumer system A, B, a smart metering system (e.g., Ma, Mb, M), a control system, a supervisory control and data acquisition ("SCADA") system, an energy management system ("EMS"), or the like. The data processing system 300 is also suitable for data processing, management, storage, and for generating, displaying, and adjusting presentations in conjunction with a user interface or a graphical user interface ("GUI"), as described below. The data processing system 300 may be a client and/or server in a client/server system. For example, the data processing system 300 may be a server system or a personal computer ("PC") system. The data processing system 300 may also be a distributed system which is deployed across multiple processors. The data processing system 300 may also be a virtual machine. The data processing system 300 includes an input device 310, at least one central processing unit ("CPU") 320, memory 330, a display 340, and an interface device 350. The input device 310 may include a keyboard, a mouse, a trackball, a touch sensitive surface or screen, a position tracking device, an eye tracking device, a camera, a tactile glove or gloves, a gesture control armband, or a similar device. The display 340 may include a computer screen, a television screen, a display screen, a terminal device, a touch sensitive display surface or screen, a hardcopy producing output device such as a printer or plotter, a head-mounted display, virtual reality ("VR") glasses, an augmented reality ("AR") display, a hologram display, or a similar device. The memory 330 may include a variety of storage devices including internal memory and external mass storage typically arranged in a hierarchy of storage as understood by those skilled in the art. For example, the memory 330 may include databases, random access memory ("RAM"), read-only memory ("ROM"), flash memory, and/or disk devices. The interface device 350 may include one or more network connections. The data processing system 300 may be adapted for communicating with other data processing systems (e.g., similar to data processing system 300) over a network 351 via the interface device 350. For example, the interface device 350 may include an interface to a network 351 such as the Internet and/or another wired or wireless network (e.g., a wireless local area network ("WLAN"), a cellular telephone network, etc.).
As such, the interface 350 may include suitable transmitters, receivers, antennae, etc. Thus, the data processing system 300 may be linked to other data processing systems by the network 351. In addition, the interface 351 may include one or more input and output connections or points for connecting various sensors, status (indication) inputs, analog (measured value) inputs, counter inputs, analog outputs, and control outputs to the data processing system 300.
In addition, the data processing system 300 may include a Global Positioning System ("GPS") receiver. The CPU 320 may include or be operatively coupled to dedicated coprocessors, memory devices, or other hardware modules 321. The CPU 320 is operatively coupled to the memory 330 which stores an operating system (e.g., 331) for general management of the system 300. The CPU
320 is operatively coupled to the input device 310 for receiving user commands, queries, or data and to the display 340 for displaying the results of these commands, queries, or data to the user.
Commands, queries, and data may also be received via the interface device 350 and results and data may be transmitted via the interface device 350. The data processing system 300 may include a data store or database system 332 for storing data and programming information. The database system 332 may include a database management system (e.g., 332) and a database (e.g., 332) and may be stored in the memory 330 of the data processing system 300. In general, the data processing system 300 has stored therein data representing sequences of instructions which when executed cause the method described herein to be performed. Of course, the data processing system 300 may contain additional software and hardware a description of which is not necessary for understanding the application.
[0032] Thus, the data processing system 300 includes computer executable programmed instructions for directing the system 300 to implement the embodiments of the present application. The programmed instructions may be embodied in one or more hardware modules 321 or software modules 331 resident in the memory 330 of the data processing system 300 or elsewhere (e.g., 320).
Alternatively, the programmed instructions may be embodied on a computer readable medium or product (e.g., one or more digital video disks ("DVDs"), compact disks ("CDs"), memory sticks, etc.) which may be used for transporting the programmed instructions to the memory 330 of the data processing system 300. Alternatively, the programmed instructions may be embedded in a computer-readable signal or signal-bearing medium or product that is uploaded to a network 351 by a vendor or supplier of the programmed instructions, and this signal or signal-bearing medium or product may be downloaded through an interface (e.g., 350) to the data processing system 300 from the network 351 by end users or potential buyers.
[0033] A user may interact with the data processing system 300 and its hardware and software modules 321, 331 using a user interface such as a graphical user interface ("GUI") 380 (and related modules 321, 331). The GUI 380 may be used for monitoring, managing, and accessing the data processing system 300. GUIs are supported by common operating systems and provide a display format which enables a user to choose commands, execute application programs, manage computer files, and perform other functions by selecting pictorial representations known as icons, or items from a menu through use of an input device 310 such as a mouse. In general, a GUI is used to convey information to and receive commands from users and generally includes a variety of GUI
objects or controls, including icons, toolbars, drop-down menus, text, dialog boxes, buttons, and the like. A user typically interacts with a GUI 380 presented on a display 340 by using an input device (e.g., a mouse) 310 to position a pointer or cursor 390 over an object (e.g., an icon) 391 and by selecting or "clicking" on the object 391. Typically, a GUI based system presents application, system status, and other information to the user in one or more "windows" appearing on the display 340. A
window 392 is a more or less rectangular area within the display 340 in which a user may view an application or a document. Such a window 392 may be open, closed, displayed full screen, reduced to an icon, increased or reduced in size, or moved to different areas of the display 340. Multiple windows may be displayed simultaneously, such as: windows included within other windows, windows overlapping other windows, or windows tiled within the display area.
[0034] FIG. 2 is a block diagram illustrating energy flows for ex-post market and settlement prices (e.g., energy clearing prices) for a microgrid 100 as determined by a microgrid market management system 500 in accordance with an embodiment of the application. Ex-post (i.e., after the fact) market clearing resolves imbalanced microgrid generation and consumption. The imbalances occur when generation and consumption within the microgrid 100 are not equal. Based on metered values, the system 500 runs a power flow calculation. If the microgrid 100 is a market participant in the wholesale energy market 400, the energy clearing prices at each node are calculated based on the substation locational marginal pricing ("LMP") as a reference price. If the microgrid 100 is not a participant in the wholesale energy market 400, but rather has a power purchase agreement with the overlaid grid operator, then the reference price is based on an excess energy credit price and/or a volumetric price. When the summary net load is positive (i.e., generation mode), the reference price is equal to the excess energy credit price. When the summary net load is negative (i.e., consumption mode), the reference price is the volumetric price.
[0035] The settlement prices are based on measured quantities as illustrated in FIG. 2. Note that the example shown in FIG. 2 disregards active power losses for simplicity. In FIG.
2, a microgrid 100 is shown having first and second prosumers or prosumer systems (or nodes) A, B
coupled to a distribution system 110. The microgrid 100 is coupled to or interconnected with a transmission grid or system 200 directly or via the distribution system 110 at a point of common coupling ("PCC") PCC. The distribution and transmission systems 110, 200 may be referred to collectively as a transmission/distribution system 200, 110 or utility transmission/distribution system 200, 110. The power flows of the first and second prosumers A, B are measured by respective first and second power meters Ma, Mb. The power flow at the PCC PCC is measured by a meter M
(e.g., a power monitor, a substation meter, etc.) located at the PCC PCC. In FIG. 2, the first prosumer A consumes kWh during a 15-minute time interval ending at 14:00 hours (for example).
During the same time-period, the second prosumer B delivers 10 kWh to the microgrid 100.
[0036] The microgrid market management ("MMM") system 500 monitors injections and absorptions of active and reactive power at the distribution system prosumers A, B and at the PCC
balancing supply and demand on different time-scales; demand-side management;
supply-side management; storage management; islanding mode management including black start in islanding mode; protection & restoration; smart metering; auto-configuration; and, planning.
.. [0010] In more detail, the main actors with respect to the operation of a microgrid include: a microgrid operator who handles the system operator, energy retailer, and aggregator roles in a traditional grid model; an overlay grid operator who is the operator of the grid to which the microgrid has a connection point; a prosumer who is a consumer, DER (e.g., PV, wind, and/or storage plant) owner, and/or storage owner; and, a service provider who provides weather forecasts, energy market analysis, etc.
[0011] With respect to microgrids and electric power trading, a microgrid also provides an open trading and communication platform for all internal and external trading. The types of markets defined in the existing literature are as follows: the general wholesale market comprising the main energy market for general national and international trading and the spot energy market for short-.. term trading; the balancing market for rebalancing supply and demand in the case of upcoming power shortages; the market for ancillary services to provide additional services like frequency control, voltage support, etc.; and, the future (regional) retail market. The retail market provides a "gate" for microgrid electric power and service trading to external markets.
It is assumed that all microgrid prosumers having a contract with the microgrid operator ("MO") and trust that the MO
will represent all of the MO's customers towards the external markets and will distribute the internal resources to the MO's customers in the best way respecting internal energy generation and consumption.
[0012] In the existing literature with respect to microgrid arrangements, it is assumed that the MO
provides the following market services: sells/buys energy on the external market; and, sells balancing and ancillary services. (See Sai Krovvidi, "Competitive Microgrid Electricity Market Design", Master of Science in Electrical Engineering Thesis, Virginia Polytechnic Institute and State University, Arlington, Virginia, 2010, which is incorporated herein by reference.) [0013] With respect to the electricity markets and market management, the following is an overview of the wholesale market and the retail market. According to the literature (see Ignacio J. Perez-Arriaga, "Engineering, Economics & Regulation of the Electric Power System", MIT, 2010, which is incorporated herein by reference), typical wholesale market products and services include the following: scheduled energy (in long-term contracts, day-ahead, intra-day and/or balancing markets);
frequency control - primary reserve, secondary reserve, tertiary reserve;
reactive power for voltage regulation; black-start capabilities; and, generation capacity for long term adequacy. Electricity prices in wholesale markets are established as follows: ISO/RTOs use a uniform (or single) clearing price auction in which electricity generators place bids with an independent market administrator for a particular time period; the independent administrator then dispatches the generators from lowest to highest bids until all power demand is met; and, each generator that is dispatched is then paid the same price as what was paid for the last unit of electric power needed to meet total demand.
[0014] With respect to the retail market, in states where full retail competition (often called "retail choice") is provided, customers may choose between their incumbent utility supplier and an array of competitive suppliers, as opposed to being a captive customer to a single provider. Competitive retail suppliers provide a variety of service plans that give consumers and businesses flexibility in their energy purchases. They may also offer services to hedge against price fluctuations, more choices for alternative energy resources, and newer energy efficiency projects, among others. These opportunities allow consumers and businesses to choose the services that best meet their needs. In retail choice states, commissions approve any alternative competitive supplier before they can serve customers. The commissions also oversee power procurement and approve the results of the process and whether the process was fair. In states not offering retail competition, the commissions regulate the expenditures of the monopoly utilities by allowing a rate of return on most costs. In these states, utilities are vertically-integrated and may construct, own, and operate power plants - at the ratepayers' expense.
[0015] However, there are several problems with the operation of existing microgrids. For example, one problem with existing microgrid electricity trading platforms and existing electricity markets is that existing solutions are focused on day ahead energy markets (e.g., day ahead scheduling of intermittent resources) and as such they do not address real-time market management needs. As another example, existing microgrids lack energy management and control solutions for real-time internal microgrid market ("micromarker) management.
[0016] A need therefore exists for an improved method and system for real-time market management for microgrids having distributed energy resources. Accordingly, a solution that addresses, at least in part, the above and other shortcomings is desired.
SUMMARY OF THE APPLICATION
[0017] According to one aspect of the application, there is provided a method for managing a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, the method comprising: using a microgrid market management ("MMM") system: establishing an energy clearing price for electrical energy within the microgrid; settling energy transactions between the first and second prosumer systems within the microsystem; aggregating distributed energy resources and controllable loads of the first and second prosumer systems within the microgrid and transmitting a bid for the aggregated distributed energy resources and controllable loads to one or more of a wholesale energy market system, an ancillary services market system, and a utility system; and, controlling the distributed energy resources and controllable loads upon receipt of control signals from one or more of the .. wholesale energy market system, the ancillary services market system, and the utility system.
[0018] According to another aspect of the application, there is provided a method for establishing an energy clearing price for electrical energy within a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, the method comprising: using a microgrid market management ("MMM") system: receiving a price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid;
monitoring electric power flow between the first and second prosumer systems and the microgrid using respective first and second prosumer meters, the first and second prosumer meters located at respective locations of the first and second prosumer systems within the microgrid; monitoring electric power flow between the microgrid and the transmission/distribution system using a meter located at a point of common coupling between the microgrid and the transmission/distribution system; and, using a processor within the MMM system, determining the energy clearing price from: the price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid; the respective locations of the first and second prosumer systems within the microgrid; and, the electric power flow between the first and second prosumer systems and the microgrid.
[0019] In accordance with further aspects of the application, there is provided an apparatus such as a data processing system, a microgrid market management system, a prosumer system, a control system, a forecasting system, etc., a method for adapting same, as well as articles of manufacture such as a computer readable medium or product and computer program product or software product (e.g., comprising a non-transitory medium) having program instructions recorded thereon for practising the method of the application.
BRIEF DESCRIPTION OF THE DRAWINGS
[0020] Further features and advantages of the embodiments of the present application will become apparent from the following detailed description, taken in combination with the appended drawings, in which:
[0021] FIG. 1 is a block diagram illustrating a microgrid in accordance with the prior art;
[0022] FIG. 2 is a block diagram illustrating energy flows for ex-post market and settlement prices for a microgrid as determined by a microgrid market management system in accordance with an embodiment of the application;
[0023] FIG. 3 is a block diagram illustrating ex-ante market and settlement prices for a microgrid as determined by a microgrid market management system in accordance with an embodiment of the application;
[0024] FIG. 4 is a block diagram illustrating frequency control aggregation by a microgrid market management system for a microgrid in accordance with an embodiment of the application;
[0025] FIG. 5 is a block diagram illustrating real-time energy market participation for a microgrid as implemented by a microgrid market management system in accordance with an embodiment of the application;
[0026] FIG. 6 is a block diagram illustrating a data processing system in accordance with an embodiment of the application; and, [0027] FIG. 7 is a flow chart illustrating operations of modules within a data processing system for managing a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, in accordance with an embodiment of the application.
[0028] It will be noted that throughout the appended drawings, like features are identified by like reference numerals.
DETAILED DESCRIPTION OF THE EXAMPLE EMBODIMENTS
[0029] In the following description, details are set forth to provide an understanding of the application. In some instances, certain software, circuits, structures and methods have not been described or shown in detail in order not to obscure the application. The term "data processing system" or "system" is used herein to refer to any machine for processing data, including the computer systems, MMM systems, prosumer systems, control systems, forecasting systems, and network arrangements described herein. The present application may be implemented in any computer programming language provided that the operating system of the data processing system provides the facilities that may support the requirements of the present application. Any limitations presented would be a result of a particular type of operating system or computer programming language and would not be a limitation of the present application. The present application may also be implemented in hardware or in a combination of hardware and software.
[0030] According to one aspect of the application, there is provided a method and system for real-time microgrid market management ("MMM") enabling internal trade within a microgrid as well as external trading with other microgrids and/or with the main distribution grid through the microgrid's open trading and communication platform. The microgrid market management method and system of the present application allows a market participant to sell excess energy to other market participants rather than to a utility allowing for a selling price that may be higher than an excess energy credit and a purchase price that may be lower than a volumetric charge.
[0031] FIG. 6 is a block diagram illustrating a data processing system 300 in accordance with an embodiment of the invention. The data processing 300 is suitable for performing as a microgrid market management ("MMM") system 500, a prosumer system A, B, a smart metering system (e.g., Ma, Mb, M), a control system, a supervisory control and data acquisition ("SCADA") system, an energy management system ("EMS"), or the like. The data processing system 300 is also suitable for data processing, management, storage, and for generating, displaying, and adjusting presentations in conjunction with a user interface or a graphical user interface ("GUI"), as described below. The data processing system 300 may be a client and/or server in a client/server system. For example, the data processing system 300 may be a server system or a personal computer ("PC") system. The data processing system 300 may also be a distributed system which is deployed across multiple processors. The data processing system 300 may also be a virtual machine. The data processing system 300 includes an input device 310, at least one central processing unit ("CPU") 320, memory 330, a display 340, and an interface device 350. The input device 310 may include a keyboard, a mouse, a trackball, a touch sensitive surface or screen, a position tracking device, an eye tracking device, a camera, a tactile glove or gloves, a gesture control armband, or a similar device. The display 340 may include a computer screen, a television screen, a display screen, a terminal device, a touch sensitive display surface or screen, a hardcopy producing output device such as a printer or plotter, a head-mounted display, virtual reality ("VR") glasses, an augmented reality ("AR") display, a hologram display, or a similar device. The memory 330 may include a variety of storage devices including internal memory and external mass storage typically arranged in a hierarchy of storage as understood by those skilled in the art. For example, the memory 330 may include databases, random access memory ("RAM"), read-only memory ("ROM"), flash memory, and/or disk devices. The interface device 350 may include one or more network connections. The data processing system 300 may be adapted for communicating with other data processing systems (e.g., similar to data processing system 300) over a network 351 via the interface device 350. For example, the interface device 350 may include an interface to a network 351 such as the Internet and/or another wired or wireless network (e.g., a wireless local area network ("WLAN"), a cellular telephone network, etc.).
As such, the interface 350 may include suitable transmitters, receivers, antennae, etc. Thus, the data processing system 300 may be linked to other data processing systems by the network 351. In addition, the interface 351 may include one or more input and output connections or points for connecting various sensors, status (indication) inputs, analog (measured value) inputs, counter inputs, analog outputs, and control outputs to the data processing system 300.
In addition, the data processing system 300 may include a Global Positioning System ("GPS") receiver. The CPU 320 may include or be operatively coupled to dedicated coprocessors, memory devices, or other hardware modules 321. The CPU 320 is operatively coupled to the memory 330 which stores an operating system (e.g., 331) for general management of the system 300. The CPU
320 is operatively coupled to the input device 310 for receiving user commands, queries, or data and to the display 340 for displaying the results of these commands, queries, or data to the user.
Commands, queries, and data may also be received via the interface device 350 and results and data may be transmitted via the interface device 350. The data processing system 300 may include a data store or database system 332 for storing data and programming information. The database system 332 may include a database management system (e.g., 332) and a database (e.g., 332) and may be stored in the memory 330 of the data processing system 300. In general, the data processing system 300 has stored therein data representing sequences of instructions which when executed cause the method described herein to be performed. Of course, the data processing system 300 may contain additional software and hardware a description of which is not necessary for understanding the application.
[0032] Thus, the data processing system 300 includes computer executable programmed instructions for directing the system 300 to implement the embodiments of the present application. The programmed instructions may be embodied in one or more hardware modules 321 or software modules 331 resident in the memory 330 of the data processing system 300 or elsewhere (e.g., 320).
Alternatively, the programmed instructions may be embodied on a computer readable medium or product (e.g., one or more digital video disks ("DVDs"), compact disks ("CDs"), memory sticks, etc.) which may be used for transporting the programmed instructions to the memory 330 of the data processing system 300. Alternatively, the programmed instructions may be embedded in a computer-readable signal or signal-bearing medium or product that is uploaded to a network 351 by a vendor or supplier of the programmed instructions, and this signal or signal-bearing medium or product may be downloaded through an interface (e.g., 350) to the data processing system 300 from the network 351 by end users or potential buyers.
[0033] A user may interact with the data processing system 300 and its hardware and software modules 321, 331 using a user interface such as a graphical user interface ("GUI") 380 (and related modules 321, 331). The GUI 380 may be used for monitoring, managing, and accessing the data processing system 300. GUIs are supported by common operating systems and provide a display format which enables a user to choose commands, execute application programs, manage computer files, and perform other functions by selecting pictorial representations known as icons, or items from a menu through use of an input device 310 such as a mouse. In general, a GUI is used to convey information to and receive commands from users and generally includes a variety of GUI
objects or controls, including icons, toolbars, drop-down menus, text, dialog boxes, buttons, and the like. A user typically interacts with a GUI 380 presented on a display 340 by using an input device (e.g., a mouse) 310 to position a pointer or cursor 390 over an object (e.g., an icon) 391 and by selecting or "clicking" on the object 391. Typically, a GUI based system presents application, system status, and other information to the user in one or more "windows" appearing on the display 340. A
window 392 is a more or less rectangular area within the display 340 in which a user may view an application or a document. Such a window 392 may be open, closed, displayed full screen, reduced to an icon, increased or reduced in size, or moved to different areas of the display 340. Multiple windows may be displayed simultaneously, such as: windows included within other windows, windows overlapping other windows, or windows tiled within the display area.
[0034] FIG. 2 is a block diagram illustrating energy flows for ex-post market and settlement prices (e.g., energy clearing prices) for a microgrid 100 as determined by a microgrid market management system 500 in accordance with an embodiment of the application. Ex-post (i.e., after the fact) market clearing resolves imbalanced microgrid generation and consumption. The imbalances occur when generation and consumption within the microgrid 100 are not equal. Based on metered values, the system 500 runs a power flow calculation. If the microgrid 100 is a market participant in the wholesale energy market 400, the energy clearing prices at each node are calculated based on the substation locational marginal pricing ("LMP") as a reference price. If the microgrid 100 is not a participant in the wholesale energy market 400, but rather has a power purchase agreement with the overlaid grid operator, then the reference price is based on an excess energy credit price and/or a volumetric price. When the summary net load is positive (i.e., generation mode), the reference price is equal to the excess energy credit price. When the summary net load is negative (i.e., consumption mode), the reference price is the volumetric price.
[0035] The settlement prices are based on measured quantities as illustrated in FIG. 2. Note that the example shown in FIG. 2 disregards active power losses for simplicity. In FIG.
2, a microgrid 100 is shown having first and second prosumers or prosumer systems (or nodes) A, B
coupled to a distribution system 110. The microgrid 100 is coupled to or interconnected with a transmission grid or system 200 directly or via the distribution system 110 at a point of common coupling ("PCC") PCC. The distribution and transmission systems 110, 200 may be referred to collectively as a transmission/distribution system 200, 110 or utility transmission/distribution system 200, 110. The power flows of the first and second prosumers A, B are measured by respective first and second power meters Ma, Mb. The power flow at the PCC PCC is measured by a meter M
(e.g., a power monitor, a substation meter, etc.) located at the PCC PCC. In FIG. 2, the first prosumer A consumes kWh during a 15-minute time interval ending at 14:00 hours (for example).
During the same time-period, the second prosumer B delivers 10 kWh to the microgrid 100.
[0036] The microgrid market management ("MMM") system 500 monitors injections and absorptions of active and reactive power at the distribution system prosumers A, B and at the PCC
10 PCC (e.g., M) where the microgrid 100 is interconnected with the transmission/distribution system 200, 110. Based on power injections and absorptions acquired by time-period and location 120, 130 (e.g., of prosumers A, B), power flows, and the physical topology of the transmission/distribution system 200, 110, the MMM system 500 mathematically balances or determines all financial transactions. The calculation method may be similar to a LMP calculation in the wholesale markets.
15 [0037] According to one embodiment, real-time communications are not necessary if the prosumer or node power meters Ma, Mb can record measurements with associated time stamps. In this case, the MMM system 500 may acquire necessary data prior to running or performing its calculations.
[0038] Wholesale market LMP reflects the value of electric energy for different locations 120, 130 at certain time periods based on load and generation levels and transmission limits. For a small microgrid 100, the price for all prosumers A, B for a certain time period may be set equal to simplify the price calculation. The MMM system 500 may communicate with the wholesale energy market 400 (i.e., a system 400 associated with the wholesale energy market) to sell surplus energy or buy energy when generation is lower than consumption within the microgrid 100.
[0039] For reference, LMP is a way for wholesale electric energy prices to reflect the value of electric energy at different locations 120, 130, accounting for the patterns of load, generation, and the physical limits of the transmission/distribution system. This principle is applicable to real-time markets in microgrids 100 that account for transactions between prosumers A, B. One feature of microgrid LMP is that selling and buying prosumers A, B may be rather electrically distant. Because of this distance (e.g., between locations 120, 130), the losses between prosumer nodes A, B should
15 [0037] According to one embodiment, real-time communications are not necessary if the prosumer or node power meters Ma, Mb can record measurements with associated time stamps. In this case, the MMM system 500 may acquire necessary data prior to running or performing its calculations.
[0038] Wholesale market LMP reflects the value of electric energy for different locations 120, 130 at certain time periods based on load and generation levels and transmission limits. For a small microgrid 100, the price for all prosumers A, B for a certain time period may be set equal to simplify the price calculation. The MMM system 500 may communicate with the wholesale energy market 400 (i.e., a system 400 associated with the wholesale energy market) to sell surplus energy or buy energy when generation is lower than consumption within the microgrid 100.
[0039] For reference, LMP is a way for wholesale electric energy prices to reflect the value of electric energy at different locations 120, 130, accounting for the patterns of load, generation, and the physical limits of the transmission/distribution system. This principle is applicable to real-time markets in microgrids 100 that account for transactions between prosumers A, B. One feature of microgrid LMP is that selling and buying prosumers A, B may be rather electrically distant. Because of this distance (e.g., between locations 120, 130), the losses between prosumer nodes A, B should
11 be considered for LMP adjustment. Another feature of microgrid LMP is that clean energy sources at prosumer nodes A, B (e.g., solar irradiation at PV systems) may also change LMP for buying/selling prosumers A, B.
[0040] In the general case, a reference LMP has the following three components: a) an energy component, that is, the price for electric energy at the point of common coupling PCC as the "reference point"; a congestion component, that is, the price discount reflecting the marginal cost of congestion at the PCC PCC; and, a loss component, that is, the price discount reflecting the cost of losses of the wholesale energy market 400 connection to the PPC PCC.
[0041] The energy component of LMP at the PCC PCC reflects the value of DERs such as solar energy generation and energy storage. The DER factor of the energy component is the load-weighted average of the DER node prices in the microgrid 100.
[0042] The congestion component of LMP at the PCC PCC is applied to energy delivered to/bought by the whole microgrid 100 from the wholesale energy market or sold from the microgrid 100 to the wholesale energy market 400. In both cases, it can be entered as: a null or zero state; a fixed value (similar to annualized values like rates or tariffs) connecting the microgrid 100 and the wholesale energy market 400; or, the published real-time values of an independent system operator ("ISO").
The congestion component defines the adjustment in electricity price (buying or selling) between the wholesale energy market 400 and the microgrid 100 and will be applied similarly to all the prosumers A, B in the microgrid 100.
[0043] The loss component of LMP at the PCC PCC is the weighted average of the loss components of the DER nodal prices that comprise the microgrid price.
[0044] In general terms, the energy component and the loss component are the two parameters that define the value between the prosumers A, B as sellers and buyers as well as the prosumers A, B
selling to or buying from the wholesale energy market 400. The congestion component defines the adjustment in electricity (buy or sell) between the wholesale energy market 400 and the microgrid 100 and may be applied similarly to all the prosumers A, B in the microgrid 100.
[0045] According to one embodiment, prosumer or nodal DER pricing in the microgrid 100 may be used to define the energy component of the reference LMP for ex-post (i.e., after the fact) and ex-
[0040] In the general case, a reference LMP has the following three components: a) an energy component, that is, the price for electric energy at the point of common coupling PCC as the "reference point"; a congestion component, that is, the price discount reflecting the marginal cost of congestion at the PCC PCC; and, a loss component, that is, the price discount reflecting the cost of losses of the wholesale energy market 400 connection to the PPC PCC.
[0041] The energy component of LMP at the PCC PCC reflects the value of DERs such as solar energy generation and energy storage. The DER factor of the energy component is the load-weighted average of the DER node prices in the microgrid 100.
[0042] The congestion component of LMP at the PCC PCC is applied to energy delivered to/bought by the whole microgrid 100 from the wholesale energy market or sold from the microgrid 100 to the wholesale energy market 400. In both cases, it can be entered as: a null or zero state; a fixed value (similar to annualized values like rates or tariffs) connecting the microgrid 100 and the wholesale energy market 400; or, the published real-time values of an independent system operator ("ISO").
The congestion component defines the adjustment in electricity price (buying or selling) between the wholesale energy market 400 and the microgrid 100 and will be applied similarly to all the prosumers A, B in the microgrid 100.
[0043] The loss component of LMP at the PCC PCC is the weighted average of the loss components of the DER nodal prices that comprise the microgrid price.
[0044] In general terms, the energy component and the loss component are the two parameters that define the value between the prosumers A, B as sellers and buyers as well as the prosumers A, B
selling to or buying from the wholesale energy market 400. The congestion component defines the adjustment in electricity (buy or sell) between the wholesale energy market 400 and the microgrid 100 and may be applied similarly to all the prosumers A, B in the microgrid 100.
[0045] According to one embodiment, prosumer or nodal DER pricing in the microgrid 100 may be used to define the energy component of the reference LMP for ex-post (i.e., after the fact) and ex-
12 ante (i.e., before the event) market pricing using real-time observed and/or forecasted solar irradiance/power resources. This may be important in situations where some of the nodal DERs have different solar irradiance levels due to natural (e.g., trees) or man-made (e.g., neighboring buildings) obstructions to sunlight at the nodal PV arrays. The same consideration may be given to energy storage and dispatchable/controllable loads.
[0046] According to another embodiment, the nodal loss component pricing in the microgrid 100 may be used to define the loss component of the reference LMP at the PCC PCC.
This is especially important for nodal DERs in geographically large microgrids having long circuit connections with other prosumers or nodes A, B in the microgrid and with the PCC PCC. This reflects the cost of losses at the nodal DER relative to the load-weighted average of the PCC
price. From this standpoint, the loss component is defined as a zero loss when DER nodes A, B
are very close and as dynamic or annualized/socialized losses per node when the DER nodes A, B are remote.
[0047] FIG. 3 is a block diagram illustrating ex-ante market and settlement prices (e.g., energy clearing prices) for a microgrid 100 as determined by a microgrid market management system 500 in accordance with an embodiment of the application. In addition to ex-post market pricing, the MMM
system 500 may optionally provide ex-ante (before the event) market pricing when the electricity price is set prior to its consumption.
[0048] FIG. 3 shows an example of ex-ante market pricing. In FIG. 3, the first prosumer A places a bid to buy 1 kWh of energy at a specified node between the future times 15:00 hours and 15:15 hours for a specified price of $0.06 per kWh. The reason for this bid on the ex-ante market could be due to a price forecast. The second prosumer B makes an offer to supply 1 kWh at the specified location and time at $0.07 per kWh. If the prices are close to each other (subject to market rules), the MMM system 500 records the future transaction at $0.065 per kWh (subject to market rules) after the price in question is confirmed by both parties A, B. Note that the time horizon of transactions is not limited to 15 minute intervals. Alternatively, depending on the market (i.e., energy and ancillary services (e.g., frequency)) and microgrid scale, a shorter time interval may be used. For example, the time interval may depend on the time horizons of various market products (e.g., 5 to 15 minute intervals for energy blocks, 10 minute intervals for ancillary services such as spinning reserve, etc.).
[0046] According to another embodiment, the nodal loss component pricing in the microgrid 100 may be used to define the loss component of the reference LMP at the PCC PCC.
This is especially important for nodal DERs in geographically large microgrids having long circuit connections with other prosumers or nodes A, B in the microgrid and with the PCC PCC. This reflects the cost of losses at the nodal DER relative to the load-weighted average of the PCC
price. From this standpoint, the loss component is defined as a zero loss when DER nodes A, B
are very close and as dynamic or annualized/socialized losses per node when the DER nodes A, B are remote.
[0047] FIG. 3 is a block diagram illustrating ex-ante market and settlement prices (e.g., energy clearing prices) for a microgrid 100 as determined by a microgrid market management system 500 in accordance with an embodiment of the application. In addition to ex-post market pricing, the MMM
system 500 may optionally provide ex-ante (before the event) market pricing when the electricity price is set prior to its consumption.
[0048] FIG. 3 shows an example of ex-ante market pricing. In FIG. 3, the first prosumer A places a bid to buy 1 kWh of energy at a specified node between the future times 15:00 hours and 15:15 hours for a specified price of $0.06 per kWh. The reason for this bid on the ex-ante market could be due to a price forecast. The second prosumer B makes an offer to supply 1 kWh at the specified location and time at $0.07 per kWh. If the prices are close to each other (subject to market rules), the MMM system 500 records the future transaction at $0.065 per kWh (subject to market rules) after the price in question is confirmed by both parties A, B. Note that the time horizon of transactions is not limited to 15 minute intervals. Alternatively, depending on the market (i.e., energy and ancillary services (e.g., frequency)) and microgrid scale, a shorter time interval may be used. For example, the time interval may depend on the time horizons of various market products (e.g., 5 to 15 minute intervals for energy blocks, 10 minute intervals for ancillary services such as spinning reserve, etc.).
13 [0049] FIG. 4 is a block diagram illustrating frequency control aggregation by a microgrid market management system 500 for a microgrid 100 in accordance with an embodiment of the application.
The MMM system 500 may aggregate prosumers A, B to facilitate bidding into the wholesale ancillary services market 700. The Federal Energy Regulatory Commission ("FERC"), for example, has identified six different kinds of ancillary services: scheduling and dispatch; reactive power and voltage control; loss compensation; load following; system protection; and, energy imbalance. FIG.
4 illustrates frequency control aggregation by the MMM system 500. Frequency control ensures that the grid frequency is within a specific range of the nominal frequency. The MMM system 500 aggregates the first and second prosumers A, B control range bids 710, 720 for certain time periods and prices and then communicates or transmits the aggregated bids 730 to the wholesale market 700 (i.e., to a system 700 associated with the wholesale market for ancillary services). The wholesale market 700 communicates or transmits back to the MMM system 500 active power commands 740 to control the grid frequency. The MMM system 500 distributes the commands 750, 760 back to the prosumers A, B. This type of participation in the ancillary services market 700 generally requires real-time communications between the prosumers A, B, the MMM system 500, and the wholesale market 700.
[0050] FIG. 5 is a block diagram illustrating real-time energy market participation for a microgrid 100 as implemented by a microgrid market management system 500 in accordance with an embodiment of the application. The MMM system 500 may implement a real-time energy market as illustrated in FIG 5. In this implementation, all the prosumers A, B willing to participate in the market periodically send bids to the MMM system 500 offering a certain amount of energy for the next time period at a certain price. For example, the second prosumer B may offer to sell 10 kWh between 15:00 hour and 15:05 hours at a price of $0.10 per kWh. Note that 10 kWh for 5 minutes equals 10/12 or 0.8333 kWh of energy. As such, the bid would be served with 120 kW of capacity for the 5 minute bid period (obligation) to provide a meter recorded value (calculated) of 120 kW x 5 minutes (1/12th of an hour) = 10 kWh.
[0051] At the beginning of the time period, the MMM system 500 may run a load forecast and selects the lowest bids to cover the forecast demand. The highest bidding price in the selected group of bids covering the load is selected as a market clearing price. All prosumers A, B generating power may get paid the same amount for delivered energy for this time period. A
shortage of energy (5
The MMM system 500 may aggregate prosumers A, B to facilitate bidding into the wholesale ancillary services market 700. The Federal Energy Regulatory Commission ("FERC"), for example, has identified six different kinds of ancillary services: scheduling and dispatch; reactive power and voltage control; loss compensation; load following; system protection; and, energy imbalance. FIG.
4 illustrates frequency control aggregation by the MMM system 500. Frequency control ensures that the grid frequency is within a specific range of the nominal frequency. The MMM system 500 aggregates the first and second prosumers A, B control range bids 710, 720 for certain time periods and prices and then communicates or transmits the aggregated bids 730 to the wholesale market 700 (i.e., to a system 700 associated with the wholesale market for ancillary services). The wholesale market 700 communicates or transmits back to the MMM system 500 active power commands 740 to control the grid frequency. The MMM system 500 distributes the commands 750, 760 back to the prosumers A, B. This type of participation in the ancillary services market 700 generally requires real-time communications between the prosumers A, B, the MMM system 500, and the wholesale market 700.
[0050] FIG. 5 is a block diagram illustrating real-time energy market participation for a microgrid 100 as implemented by a microgrid market management system 500 in accordance with an embodiment of the application. The MMM system 500 may implement a real-time energy market as illustrated in FIG 5. In this implementation, all the prosumers A, B willing to participate in the market periodically send bids to the MMM system 500 offering a certain amount of energy for the next time period at a certain price. For example, the second prosumer B may offer to sell 10 kWh between 15:00 hour and 15:05 hours at a price of $0.10 per kWh. Note that 10 kWh for 5 minutes equals 10/12 or 0.8333 kWh of energy. As such, the bid would be served with 120 kW of capacity for the 5 minute bid period (obligation) to provide a meter recorded value (calculated) of 120 kW x 5 minutes (1/12th of an hour) = 10 kWh.
[0051] At the beginning of the time period, the MMM system 500 may run a load forecast and selects the lowest bids to cover the forecast demand. The highest bidding price in the selected group of bids covering the load is selected as a market clearing price. All prosumers A, B generating power may get paid the same amount for delivered energy for this time period. A
shortage of energy (5
14 kWh in the example of FIG. 5) may be purchased on the wholesale energy market 400 at a wholesale price. Energy surplus may be sold on the wholesale energy market 400 as well.
This implementation generally requires real-time communications between prosumers A, B, the MMM
system 500, and the wholesale energy market 400.
[0052] Referring to FIGS. 2-5, the MMM management system 500 acquires metering data from market participants to provide settlements between them and the utility. It may also provide the following information for market participants: current, historical, and forecast net load and summary net load, excess energy price, and volumetric price. Furthermore, the MMM
system 500 may provide prosumers A, B with the following information in real-time over a variety of communications networks: active and reactive power flow at the point of common coupling FCC;
reference price at the point of common coupling FCC; ancillary services price; voltage at the point of common coupling FCC; microgrid power flows and voltages (optionally); forecast power flows; forecast reference energy price; ancillary services price forecast; loads forecasts;
and, power generation forecasts.
[0053] Thus, according to one embodiment, there is provided a method for establishing an energy clearing price for electrical energy within a microgrid 100, the microgrid 100 including at least a first prosumer system A and a second prosumer system B electrically coupled to a transmission/distribution system 200, 110, the method comprising: using a microgrid market management ("MMM") system 500: receiving a price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100; monitoring electric power flow between the first and second prosumer systems A, B and the microgrid 100 using respective first and second prosumer meters Ma, Mb, the first and second prosumer meters Ma, Mb located at respective locations 120, 130 of the first and second prosumer systems A, B within the microgrid 100;
monitoring electric power flow between the microgrid 100 and the transmission/distribution system 200, 110 using a meter M located at a point of common coupling ("PCC") FCC between the microgrid 100 and the transmission/distribution system 200, 110; and, using a processor 320 within the MMM system 500, determining the energy clearing price from: the price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100; the respective locations 120, 130 of the first and second prosumer systems A, B within the microgrid 100; and, the electric power flow between the first and second prosumer systems A, B and the microgrid 100.
[0054] In the above method, the energy clearing price may be determined from time-stamped data retrieved from the first and second prosumer meters Ma, Mb and the meter M
located at the PCC
PCC. The energy clearing price may be determined in real-time. The price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100 may be received from a wholesale energy market system 400 or a utility system. The method may further include:
receiving messages containing bids and offers for electrical energy from at least one of the first and second prosumer systems A, B; and, by running an auction at the MMM system 500, determining the energy clearing price based on the bids and offers and on the price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100. At least one of the first and second prosumer systems A, B
may include a distributed energy resource ("DER") and wherein the DER includes one or more of a solar photovoltaic ("PV") power plant, a wind power plant, and a storage power plant. The microgrid 100 may be electrically coupled to the transmission/distribution system 200, 110 at the PCC PCC.
The transmission/distribution system 200, 110 may be a utility transmission/distribution system 200, 110. The respective locations 120, 130 of the first and second prosumer systems A, B may be electrically distant from each other. The energy clearing price may be further determined from electrical power losses between the respective locations 120, 130 of the first and second prosumer systems A, B and the PCC PCC. The energy clearing price may be further determined from respective DER costs at the one or more of the first and second prosumer systems A, B. The energy clearing price may be further determined from a marginal cost of congestion at the PCC PCC. The price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100 may be a proxy price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100. And, the first prosumer meter Ma, the second prosumer meter Mb, and the meter M located at the PCC PCC may be smart meters.
[0055] Aspects of the above described methods and systems may be summarized with the aid of a flowchart.
[0056] FIG. 7 is a flow chart illustrating operations 1000 of modules (e.g., 331) within a data processing system 300 (e.g., a MMM system 500) for managing a microgrid 100, the microgrid 100 including at least a first prosumer system A and a second prosumer system B
electrically coupled to a transmission/distribution system 200, 110, in accordance with an embodiment of the application.
[0057] At step 1001, the operations 1000 start.
[0058] At step 1002, using a microgrid market management ("MMM") system 500, an energy clearing price for electrical energy within the microgrid 100 is established.
[0059] At step 1003, energy transactions between the first and second prosumer systems A, B within the microgrid 100 are settled.
[0060] At step 1004, distributed energy resources and controllable loads of the first and second prosumer systems A, B within the microgrid 100 are aggregated and a bid for the aggregated distributed energy resources and controllable loads is transmitted to one or more of a wholesale energy market system 400, an ancillary services market system 700, and a utility system (e.g., 300).
[0061] At step 1005, the distributed energy resources and controllable loads are controlled upon receipt of control signals from one or more of the wholesale energy market system 400, the ancillary services market system 700, and the utility system (e.g., 300).
[0062] At step 1006, the operations 1000 end.
[0063] According to one embodiment, each of the above steps 1001-1006 may be implemented by a respective software module 331. According to another embodiment, each of the above steps 1001-1006 may be implemented by a respective hardware module 321 (e.g., application-specific hardware 321). According to another embodiment, each of the above steps 1001-1006 may be implemented by a combination of software 331 and hardware modules 321. For example, FIG. 7 may represent a .. block diagram illustrating the interconnection of application-specific hardware modules 1001-1006 (collectively 321) within the data processing system or systems 300, each hardware module 1001-1006 adapted or configured to implement at least a respective step of the method of the application.
[0064] According to one embodiment, certain implementations of the functionality of the present application are sufficiently mathematically, computationally, or technically complex that application-specific hardware (e.g., 321) or one or more physical computing devices (e.g., 300) (using appropriate executable instructions (e.g., 331)) may be necessary or essential to perform that functionality, for example, due to the volume or complexity of the calculations involved and/or to provide results substantially in real-time.
[0065] While this application is primarily discussed as a method, a person of ordinary skill in the art will understand that the apparatus discussed above with reference to a data processing system 300 may be programmed to enable the practice of the method of the application.
Moreover, an article of manufacture for use with a data processing system 300, such as a pre-recorded storage device or other similar computer readable medium or computer program product including program instructions recorded thereon, may direct the data processing system 300 to facilitate the practice of the method of the application. It is understood that such apparatus, products, and articles of manufacture also come within the scope of the application.
[0066] In particular, the sequences of instructions which when executed cause the method described herein to be performed by the data processing system 300 may be contained in a data carrier product according to one embodiment of the application. This data carrier product may be loaded into and run by the data processing system 300. In addition, the sequences of instructions which when executed cause the method described herein to be performed by the data processing system 300 may be contained in a computer software product or computer program product (e.g., comprising a non-transitory medium) according to one embodiment of the application. This computer software product or computer program product may be loaded into and run by the data processing system 300.
Moreover, the sequences of instructions which when executed cause the method described herein to be performed by the data processing system 300 may be contained in an integrated circuit product (e.g., a hardware module or modules 321) which may include a coprocessor or memory according to one embodiment of the application. This integrated circuit product may be installed in the data processing system 300.
[0067] The embodiments of the application described above are intended to be examples only.
Those skilled in the art will understand that various modifications of detail may be made to these embodiments, all of which come within the scope of the application.
This implementation generally requires real-time communications between prosumers A, B, the MMM
system 500, and the wholesale energy market 400.
[0052] Referring to FIGS. 2-5, the MMM management system 500 acquires metering data from market participants to provide settlements between them and the utility. It may also provide the following information for market participants: current, historical, and forecast net load and summary net load, excess energy price, and volumetric price. Furthermore, the MMM
system 500 may provide prosumers A, B with the following information in real-time over a variety of communications networks: active and reactive power flow at the point of common coupling FCC;
reference price at the point of common coupling FCC; ancillary services price; voltage at the point of common coupling FCC; microgrid power flows and voltages (optionally); forecast power flows; forecast reference energy price; ancillary services price forecast; loads forecasts;
and, power generation forecasts.
[0053] Thus, according to one embodiment, there is provided a method for establishing an energy clearing price for electrical energy within a microgrid 100, the microgrid 100 including at least a first prosumer system A and a second prosumer system B electrically coupled to a transmission/distribution system 200, 110, the method comprising: using a microgrid market management ("MMM") system 500: receiving a price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100; monitoring electric power flow between the first and second prosumer systems A, B and the microgrid 100 using respective first and second prosumer meters Ma, Mb, the first and second prosumer meters Ma, Mb located at respective locations 120, 130 of the first and second prosumer systems A, B within the microgrid 100;
monitoring electric power flow between the microgrid 100 and the transmission/distribution system 200, 110 using a meter M located at a point of common coupling ("PCC") FCC between the microgrid 100 and the transmission/distribution system 200, 110; and, using a processor 320 within the MMM system 500, determining the energy clearing price from: the price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100; the respective locations 120, 130 of the first and second prosumer systems A, B within the microgrid 100; and, the electric power flow between the first and second prosumer systems A, B and the microgrid 100.
[0054] In the above method, the energy clearing price may be determined from time-stamped data retrieved from the first and second prosumer meters Ma, Mb and the meter M
located at the PCC
PCC. The energy clearing price may be determined in real-time. The price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100 may be received from a wholesale energy market system 400 or a utility system. The method may further include:
receiving messages containing bids and offers for electrical energy from at least one of the first and second prosumer systems A, B; and, by running an auction at the MMM system 500, determining the energy clearing price based on the bids and offers and on the price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100. At least one of the first and second prosumer systems A, B
may include a distributed energy resource ("DER") and wherein the DER includes one or more of a solar photovoltaic ("PV") power plant, a wind power plant, and a storage power plant. The microgrid 100 may be electrically coupled to the transmission/distribution system 200, 110 at the PCC PCC.
The transmission/distribution system 200, 110 may be a utility transmission/distribution system 200, 110. The respective locations 120, 130 of the first and second prosumer systems A, B may be electrically distant from each other. The energy clearing price may be further determined from electrical power losses between the respective locations 120, 130 of the first and second prosumer systems A, B and the PCC PCC. The energy clearing price may be further determined from respective DER costs at the one or more of the first and second prosumer systems A, B. The energy clearing price may be further determined from a marginal cost of congestion at the PCC PCC. The price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100 may be a proxy price for electrical energy delivered to the microgrid 100 from the transmission/distribution system 200, 110 or delivered to the transmission/distribution system 200, 110 from the microgrid 100. And, the first prosumer meter Ma, the second prosumer meter Mb, and the meter M located at the PCC PCC may be smart meters.
[0055] Aspects of the above described methods and systems may be summarized with the aid of a flowchart.
[0056] FIG. 7 is a flow chart illustrating operations 1000 of modules (e.g., 331) within a data processing system 300 (e.g., a MMM system 500) for managing a microgrid 100, the microgrid 100 including at least a first prosumer system A and a second prosumer system B
electrically coupled to a transmission/distribution system 200, 110, in accordance with an embodiment of the application.
[0057] At step 1001, the operations 1000 start.
[0058] At step 1002, using a microgrid market management ("MMM") system 500, an energy clearing price for electrical energy within the microgrid 100 is established.
[0059] At step 1003, energy transactions between the first and second prosumer systems A, B within the microgrid 100 are settled.
[0060] At step 1004, distributed energy resources and controllable loads of the first and second prosumer systems A, B within the microgrid 100 are aggregated and a bid for the aggregated distributed energy resources and controllable loads is transmitted to one or more of a wholesale energy market system 400, an ancillary services market system 700, and a utility system (e.g., 300).
[0061] At step 1005, the distributed energy resources and controllable loads are controlled upon receipt of control signals from one or more of the wholesale energy market system 400, the ancillary services market system 700, and the utility system (e.g., 300).
[0062] At step 1006, the operations 1000 end.
[0063] According to one embodiment, each of the above steps 1001-1006 may be implemented by a respective software module 331. According to another embodiment, each of the above steps 1001-1006 may be implemented by a respective hardware module 321 (e.g., application-specific hardware 321). According to another embodiment, each of the above steps 1001-1006 may be implemented by a combination of software 331 and hardware modules 321. For example, FIG. 7 may represent a .. block diagram illustrating the interconnection of application-specific hardware modules 1001-1006 (collectively 321) within the data processing system or systems 300, each hardware module 1001-1006 adapted or configured to implement at least a respective step of the method of the application.
[0064] According to one embodiment, certain implementations of the functionality of the present application are sufficiently mathematically, computationally, or technically complex that application-specific hardware (e.g., 321) or one or more physical computing devices (e.g., 300) (using appropriate executable instructions (e.g., 331)) may be necessary or essential to perform that functionality, for example, due to the volume or complexity of the calculations involved and/or to provide results substantially in real-time.
[0065] While this application is primarily discussed as a method, a person of ordinary skill in the art will understand that the apparatus discussed above with reference to a data processing system 300 may be programmed to enable the practice of the method of the application.
Moreover, an article of manufacture for use with a data processing system 300, such as a pre-recorded storage device or other similar computer readable medium or computer program product including program instructions recorded thereon, may direct the data processing system 300 to facilitate the practice of the method of the application. It is understood that such apparatus, products, and articles of manufacture also come within the scope of the application.
[0066] In particular, the sequences of instructions which when executed cause the method described herein to be performed by the data processing system 300 may be contained in a data carrier product according to one embodiment of the application. This data carrier product may be loaded into and run by the data processing system 300. In addition, the sequences of instructions which when executed cause the method described herein to be performed by the data processing system 300 may be contained in a computer software product or computer program product (e.g., comprising a non-transitory medium) according to one embodiment of the application. This computer software product or computer program product may be loaded into and run by the data processing system 300.
Moreover, the sequences of instructions which when executed cause the method described herein to be performed by the data processing system 300 may be contained in an integrated circuit product (e.g., a hardware module or modules 321) which may include a coprocessor or memory according to one embodiment of the application. This integrated circuit product may be installed in the data processing system 300.
[0067] The embodiments of the application described above are intended to be examples only.
Those skilled in the art will understand that various modifications of detail may be made to these embodiments, all of which come within the scope of the application.
Claims (21)
1. A method for establishing an energy clearing price for electrical energy within a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, the method comprising:
using a microgrid market management ("MMM") system:
receiving a price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid;
monitoring electric power flow between the first and second prosumer systems and the microgrid using respective first and second prosumer meters, the first and second prosumer meters located at respective locations of the first and second prosumer systems within the microgrid;
monitoring electric power flow between the microgrid and the transmission/distribution system using a meter located at a point of common coupling ("PCC") between the microgrid and the transmission/distribution system; and, using a processor within the MMM system, determining the energy clearing price from:
the price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid;
the respective locations of the first and second prosumer systems within the microgrid; and, the electric power flow between the first and second prosumer systems and the microgrid.
using a microgrid market management ("MMM") system:
receiving a price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid;
monitoring electric power flow between the first and second prosumer systems and the microgrid using respective first and second prosumer meters, the first and second prosumer meters located at respective locations of the first and second prosumer systems within the microgrid;
monitoring electric power flow between the microgrid and the transmission/distribution system using a meter located at a point of common coupling ("PCC") between the microgrid and the transmission/distribution system; and, using a processor within the MMM system, determining the energy clearing price from:
the price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid;
the respective locations of the first and second prosumer systems within the microgrid; and, the electric power flow between the first and second prosumer systems and the microgrid.
2. The method of claim 1, wherein the energy clearing price is determined from time-stamped data retrieved from the first and second prosumer meters and the meter located at the PCC.
3. The method of claim 1, wherein the energy clearing price is determined in real-time.
4. The method of claim 1, wherein the price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid is received from a wholesale energy market system or a utility system.
5. The method of claim 1, further comprising: receiving messages containing bids and offers for electrical energy from at least one of the first and second prosumer systems;
and, by running an auction at the MMM system, determining the energy clearing price based on the bids and offers and on the price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid.
and, by running an auction at the MMM system, determining the energy clearing price based on the bids and offers and on the price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid.
6. The method of claim 1, wherein at least one of the first and second prosumer systems includes a distributed energy resource ("DER") and wherein the DER includes one or more of a solar photovoltaic ("PV") power plant, a wind power plant, and a storage power plant.
7. The method of claim 1, wherein the microgrid is electrically coupled to the transmission/distribution system at the PCC.
8. The method of claim 1, wherein the transmission/distribution system is a utility transmission/distribution system.
9. The method of claim 6, wherein the respective locations of the first and second prosumer systems are electrically distant from each other.
10. The method of claim 9, wherein the energy clearing price is further determined from electrical power losses between the respective locations of the first and second prosumer systems and the PCC.
11. The method of claim 9, wherein the energy clearing price is further determined from respective DER costs at the one or more of the first and second prosumer systems.
12. The method of claim 9, wherein the energy clearing price is further determined from a marginal cost of congestion at the PCC.
13. The method of claim 1, wherein the price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid is a proxy price for electrical energy delivered to the microgrid from the transmission/distribution system or delivered to the transmission/distribution system from the microgrid.
14. The method of claim 1, wherein the first prosumer meter, the second prosumer meter, and the meter located at the PCC are smart meters.
15. A microgrid market management ("MMM") system for establishing an energy clearing price for electrical energy within a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, the system comprising:
a processor coupled to memory; and, at least one of hardware and software modules within the memory and controlled or executed by the processor, the modules including computer readable instructions executable by the processor for causing the MMM system to implement the method of any one of claims 1 to 14.
a processor coupled to memory; and, at least one of hardware and software modules within the memory and controlled or executed by the processor, the modules including computer readable instructions executable by the processor for causing the MMM system to implement the method of any one of claims 1 to 14.
16. The system of claim 15, wherein the processor is a real-time enabling application-specific processor.
17. The system of claim 15, wherein the hardware modules are real-time enabling application-specific hardware modules.
18. A method for managing a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, the method comprising:
using a microgrid market management ("MMM") system:
establishing an energy clearing price for electrical energy within the microgrid;
settling energy transactions between the first and second prosumer systems within the microsystem;
aggregating distributed energy resources and controllable loads of the first and second prosumer systems within the microgrid and transmitting a bid for the aggregated distributed energy resources and controllable loads to one or more of a wholesale energy market system, an ancillary services market system, and a utility system; and, controlling the distributed energy resources and controllable loads upon receipt of control signals from one or more of the wholesale energy market system, the ancillary services market system, and the utility system.
using a microgrid market management ("MMM") system:
establishing an energy clearing price for electrical energy within the microgrid;
settling energy transactions between the first and second prosumer systems within the microsystem;
aggregating distributed energy resources and controllable loads of the first and second prosumer systems within the microgrid and transmitting a bid for the aggregated distributed energy resources and controllable loads to one or more of a wholesale energy market system, an ancillary services market system, and a utility system; and, controlling the distributed energy resources and controllable loads upon receipt of control signals from one or more of the wholesale energy market system, the ancillary services market system, and the utility system.
19. A microgrid market management ("MMM") system for managing a microgrid, the microgrid including at least a first prosumer system and a second prosumer system electrically coupled to a transmission/distribution system, the MMM system comprising:
a processor coupled to memory; and, at least one of hardware and software modules within the memory and controlled or executed by the processor, the modules including computer readable instructions executable by the processor for causing the MMM system to implement the method of claim 18.
a processor coupled to memory; and, at least one of hardware and software modules within the memory and controlled or executed by the processor, the modules including computer readable instructions executable by the processor for causing the MMM system to implement the method of claim 18.
20. The system of claim 19, wherein the processor is a real-time enabling application-specific processor.
21. The system of claim 19. wherein the hardware modules are real-time enabling application-specific hardware modules.
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| IT202100018737A1 (en) * | 2021-07-15 | 2023-01-15 | Intendo Srl | Method for the management of energy exchanges from self-production |
| CN113917978A (en) * | 2021-10-19 | 2022-01-11 | 华能浙江能源销售有限责任公司 | Electric power spot market auxiliary quotation system |
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| US9077204B2 (en) * | 2011-07-20 | 2015-07-07 | Inventus Holdings, Llc | Dispatchable renewable energy generation, control and storage facility |
| US8571955B2 (en) * | 2011-08-18 | 2013-10-29 | Siemens Aktiengesellschaft | Aggregator-based electric microgrid for residential applications incorporating renewable energy sources |
| WO2013082698A1 (en) * | 2011-12-05 | 2013-06-13 | Hatch Ltd. | System, method and controller for managing and controlling a micro-grid |
| EP2998923A1 (en) * | 2014-09-16 | 2016-03-23 | Atos IT Solutions and Services GmbH | Energy balancing |
| WO2016176727A1 (en) * | 2015-05-01 | 2016-11-10 | The University Of Sydney | Operation scheduling of power generation, storage and load |
| CN105320996A (en) * | 2015-08-13 | 2016-02-10 | 南方电网科学研究院有限责任公司 | Random matching trading method of microgrid electric energy |
| US20170169525A1 (en) * | 2015-12-10 | 2017-06-15 | Open Access Technology International, Inc. | Systems to electronically catalog and generate documentation for retail-level power |
| ES2773478T3 (en) * | 2016-03-01 | 2020-07-13 | Siemens Ag | Procedure and system to operate an autonomous energy supply network |
| CN106355477A (en) * | 2016-09-20 | 2017-01-25 | 广东工业大学 | Region power market transaction control method and system |
| KR101774288B1 (en) * | 2016-12-22 | 2017-09-07 | 주식회사 삼신기전 | Energy prosumer unit of one body type and method, integration energy management system including it and method thereof |
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