WO2018049504A1 - Procédé et système d'établissement en temps réel d'un prix de rajustement d'énergie pour des micro-réseaux ayant des ressources énergétiques distribuées - Google Patents

Procédé et système d'établissement en temps réel d'un prix de rajustement d'énergie pour des micro-réseaux ayant des ressources énergétiques distribuées Download PDF

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Publication number
WO2018049504A1
WO2018049504A1 PCT/CA2017/000202 CA2017000202W WO2018049504A1 WO 2018049504 A1 WO2018049504 A1 WO 2018049504A1 CA 2017000202 W CA2017000202 W CA 2017000202W WO 2018049504 A1 WO2018049504 A1 WO 2018049504A1
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WIPO (PCT)
Prior art keywords
microgrid
prosumer
energy
transmission
distribution system
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PCT/CA2017/000202
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English (en)
Inventor
Alexandre PAVLOVSKI
Dmitriy ANICHKOV
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Green Power Labs Inc.
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
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Publication date
Application filed by Green Power Labs Inc. filed Critical Green Power Labs Inc.
Priority to CA3036431A priority Critical patent/CA3036431A1/fr
Publication of WO2018049504A1 publication Critical patent/WO2018049504A1/fr

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Classifications

    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q30/00—Commerce
    • G06Q30/02—Marketing; Price estimation or determination; Fundraising
    • G06Q30/0283—Price estimation or determination
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00006—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment
    • H02J13/00028—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network characterised by information or instructions transport means between the monitoring, controlling or managing units and monitored, controlled or operated power network element or electrical equipment involving the use of Internet protocols
    • H—ELECTRICITY
    • H02—GENERATION; CONVERSION OR DISTRIBUTION OF ELECTRIC POWER
    • H02J—CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
    • H02J13/00—Circuit arrangements for providing remote indication of network conditions, e.g. an instantaneous record of the open or closed condition of each circuitbreaker in the network; Circuit arrangements for providing remote control of switching means in a power distribution network, e.g. switching in and out of current consumers by using a pulse code signal carried by the network
    • H02J13/00032—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for
    • H02J13/00034—Systems characterised by the controlled or operated power network elements or equipment, the power network elements or equipment not otherwise provided for the elements or equipment being or involving an electric power substation
    • G—PHYSICS
    • G06—COMPUTING; CALCULATING OR COUNTING
    • G06Q—INFORMATION AND COMMUNICATION TECHNOLOGY [ICT] SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES; SYSTEMS OR METHODS SPECIALLY ADAPTED FOR ADMINISTRATIVE, COMMERCIAL, FINANCIAL, MANAGERIAL OR SUPERVISORY PURPOSES, NOT OTHERWISE PROVIDED FOR
    • G06Q50/00—Systems or methods specially adapted for specific business sectors, e.g. utilities or tourism
    • G06Q50/06—Electricity, gas or water supply

Definitions

  • 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.
  • DERs may include solar photovoltaic (“PV”) power plants, wind power plants, and power storage (e.g., battery, etc.) plants.
  • PV solar photovoltaic
  • wind power plants e.g., wind power plants
  • power storage e.g., battery, etc.
  • 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.
  • 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.
  • 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-201 1-285135, FINSENY, D.3.1 vl .O, 201 1, 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.
  • 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").
  • VPPs virtual power plants
  • 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.
  • 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.
  • DER e.g., PV, wind, and/or storage plant
  • a microgrid 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.
  • MO microgrid operator
  • 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.
  • microgrids there are several problems with the operation of existing microgrids.
  • 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.
  • existing microgrids lack energy management and control solutions for real-time internal microgrid market (“micromarket”) management.
  • micromarket real-time internal microgrid market
  • a method for managing a 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.
  • MMM microgrid market management
  • 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
  • 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.
  • FIG. 1 is a block diagram illustrating a microgrid in accordance with the prior art
  • 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;
  • 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;
  • 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;
  • 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;
  • FIG. 6 is a block diagram illustrating a data processing system in accordance with an embodiment of the application;
  • 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.
  • 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.
  • 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.
  • microgrid market management 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.
  • MMM microgrid market management
  • 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.
  • 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 (“SCAD A”) 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.
  • 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.
  • 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.
  • 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.).
  • WLAN wireless local area network
  • the interface 350 may include suitable transmitters, receivers, antennae, etc.
  • the data processing system 300 may be linked to other data processing systems by the network 351.
  • 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.
  • 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.
  • 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.
  • the data processing system 300 has stored therein data representing sequences of instructions which when executed cause the method described herein to be performed.
  • the data processing system 300 may contain additional software and hardware a description of which is not necessary for understanding the application.
  • 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).
  • 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.
  • DVDs digital video disks
  • CDs compact disks
  • memory sticks etc.
  • 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.
  • 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).
  • GUI graphical user interface
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • LMP substation locational marginal pricing
  • the reference price is based on an excess energy credit price and/or a volumetric price.
  • the summary net load is positive (i.e., generation mode)
  • the reference price is equal to the excess energy credit price.
  • the summary net load is negative (i.e., consumption mode)
  • the reference price is the volumetric price.
  • 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.
  • a meter M e.g., a power monitor, a substation meter, etc. located at the PCC PCC.
  • the first prosumer A consumes 15 kWh during a 15-minute time interval ending at 14:00 hours (for example).
  • the second prosumer B delivers 10 kWh to the microgrid 100.
  • 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 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. [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.
  • 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.
  • 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 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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- 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 DE s 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.
  • 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.
  • 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.
  • the MMM system 500 may optionally provide ex-ante (before the event) market pricing when the electricity price is set prior to its consumption.
  • FIG. 3 shows an example of ex-ante market pricing.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 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.
  • 10 kWh for 5 minutes equals 10/12 or 0.8333 kWh of energy.
  • 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 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.
  • 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 PCC; reference price at the point of common coupling PCC; ancillary services price; voltage at the point of common coupling PCC; microgrid power flows and voltages (optionally); forecast power flows; forecast reference energy price; ancillary services price forecast; loads forecasts; and, power generation forecasts.
  • 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
  • MMM microgrid market management
  • 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.
  • 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.
  • DER distributed energy resource
  • 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.
  • the first prosumer meter Ma, the second prosumer meter Mb, and the meter M located at the PCC PCC may be smart meters.
  • 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.
  • modules e.g., 331
  • a data processing system 300 e.g., a MMM system 500
  • 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.
  • step 1001 the operations 1000 start.
  • 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.
  • MMM microgrid market management
  • 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).
  • 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).
  • each of the above steps 1001-1006 may be implemented by a respective software module 331.
  • each of the above steps 1001- 1006 may be implemented by a respective hardware module 321 (e.g., application-specific hardware 321).
  • each of the above steps 1001-1006 may be implemented by a combination of software 331 and hardware modules 321.
  • 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.
  • 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.
  • application-specific hardware e.g., 321
  • one or more physical computing devices e.g., 300
  • appropriate executable instructions e.g., 331
  • This data carrier product may be loaded into and run by the data processing system 300.
  • 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.
  • 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.

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Abstract

L'invention concerne un procédé d'établissement d'un prix de rajustement d'énergie pour une énergie électrique à l'intérieur d'un micro-réseau. Le procédé consiste à recevoir, au niveau d'un système de gestion de marché de micro-réseau (" MMM "), un prix pour l'énergie électrique délivrée au micro-réseau à partir d'un système de transmission/distribution ou du système de transmission/distribution à partir du micro-réseau ; à surveiller un flux d'énergie électrique entre un premier et un second système de consommateurs productifs et le micro-réseau à l'aide de premier et second compteurs de consommateurs productifs situés à des emplacements respectifs desdits premier et second systèmes de consommateurs productifs à l'intérieur du micro-réseau ; à surveiller un flux d'énergie électrique entre le micro-réseau électrique et le système de transmission/distribution à l'aide d'un compteur situé au niveau d'un point de couplage commun (" PCC ") entre le micro-réseau et le système de transmission/distribution ; et à déterminer, au niveau du MMM, le prix de rajustement d'énergie à partir du prix de l'énergie électrique fournie au micro-réseau à partir du système de transmission/distribution ou du système de transmission/distribution à partir du micro-réseau ; les emplacements respectifs des premier et second systèmes de consommateurs productifs à l'intérieur du micro-réseau ; et le flux d'énergie électrique entre les premier et second systèmes de consommateurs productifs et le micro-réseau.
PCT/CA2017/000202 2016-09-13 2017-09-12 Procédé et système d'établissement en temps réel d'un prix de rajustement d'énergie pour des micro-réseaux ayant des ressources énergétiques distribuées WO2018049504A1 (fr)

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