Method for controlling a system comprising an electrical energy source, control device, and corresponding computer program

Abstract

This disclosure relates to a method for controlling a system that forms a source of electrical power and is intended to be connected to an electrical network via an inverter controlled in voltage source mode according to a vector control algorithm for the amplitude and phase of the AC voltage of said inverter. The vector control algorithm includes a power-sharing function for the active power of the system, fed at its input by an active power or frequency setpoint, called the original vector control setpoint, and delivering at its output a phase of the AC voltage.Such a process includes: - a calculation (1) of a modified vector control setpoint; - a compensation (2) of the original vector control setpoint based on the modified vector control setpoint, delivering a reference vector control setpoint intended to feed the active power-sharing function instead of the original setpoint. Abstract figure: Figure 4.

Description

Title of the invention: Method for controlling a system forming an electrical energy source, corresponding control device and computer program Technical field

[0001] The present disclosure relates to the field of Electrical Systems (ES), and more particularly to such systems forming a source of electrical energy, and intended to be connected to an electrical network. The present disclosure is particularly, but not exclusively, concerned with the stability and frequency resistance of alternating current (AC) ES to which battery-based electrical energy storage systems (ESSEE) controlled in "grid forming" mode are connected. Prior art

[0002] It is recalled that such electrical energy storage systems constitute a reserve power capacity that can be mobilized by the electricity network manager to adapt the production-consumption balance, and thus ensure the maintenance, on the electricity network, of a stable frequency, close to its nominal value.

[0003] Frequency adjustment in fact meets two requirements: user satisfaction and the operational safety of the electrical system. Maintaining the frequency close to its nominal value is necessary for the proper functioning of electrical equipment and processes of network users, designed for operation over a given frequency range. Excessive frequency excursions are unacceptable for certain equipment and can lead to malfunctions in users' installations. Furthermore, to ensure the operational safety of the system, frequency collapses, which can occur when the production-consumption balance is negative, must be avoided.

[0004] The term "grid forming" designates in the literature a family of control algorithms for voltage inverters based on semiconductors of the transistor family (generally of the IGBT subfamily ("Insulated Gate Bipolar Transistor") but also that of MOSFET ("Metal Oxide Semiconductor Field Effect Transistor"). Since "grid forming" algorithms are not governed by standards, scientific publications and industrial solutions present significant differences. Nevertheless, there seems to be a scientific consensus on the points below: 1. These are vector control algorithms for the alternating voltage of the voltage inverters, i.e. controlling both its effective value and its phase (and therefore by extension its frequency); 2. They can operate without any other voltage source on the electrical network to which the inverters are connected (unlike the family of “grid following” and / or “grid feeding” type control algorithms).

[0005] Such "grid forming" algorithms are notably designed to instantly contribute to the supply of production-consumption imbalances. In this respect, they perform the same function as the kinetic energy reserve of conventional production, more commonly called inertia in the field of electrical systems, which have the physical property of storing, in their mechanical part, kinetic energy, which contributes to the stability of the electrical network. Indeed, in the event of a failure, inertia is capable of immediately compensating for the power imbalance and limits frequency variations, which contributes to the stability of the system.

[0006] The vast majority of grid forming algorithms include load sharing functions that allow them to synchronize with other sources in an electrical network. These load sharing functions are divided into an active power sharing function and a reactive power sharing function.

[0007] In addition to a few technical demonstrators concerning renewable energy sources, “grid forming” algorithms have been used to control battery-based SSEEs for around ten years for “microgrid” applications with satisfactory results concerning the quality of customer power supply.

[0008] It is recalled that the term "microgrid", or in French "micro network", designates an autonomous electrical system whose highest voltage level is an HTA voltage level (< 50 kV). Many isolated territories in the world correspond to this definition. In such micro-networks, battery-based ESSEEs are used to provide additional electrical power to renewable energy sources, and "grid forming" allows operation for part of the day without conventional production and improves stability throughout the day.

[0009] More recently, managers of HTB island networks (i.e., electricity transmission networks made up of high-voltage lines) and even interconnected networks have begun to take an interest in grid-forming SSEEs, and some technical demonstrators have emerged in order to evaluate their potential as a solution to certain problems such as frequency stability in a context of declining inertia in SEs, resulting in particular from the growing increase in the share of renewable energy sources in network production.

[0010] Two main families of “grid forming” algorithms are currently in use, both in scientific literature and in industrial projects: - “droop” type algorithms; - “VSM” type algorithms (for “Virtual Synchronous Machine”).

[0011] These two types of algorithm, although ensuring the same function, have different dynamic performances.

[0012] In the context of the present disclosure, we are particularly interested in the load sharing algorithms, and in particular the active power sharing algorithms of these two families of algorithms. These have a common structure with two variants: - a variant with active power setpoint PC(ms gf, illustrated in the form of a block diagram in [Fig.l]; - a variant with electrical frequency setpoint f GF, illustrated in the form of a block diagram in [Fig.2].

[0013] These algorithms are generally implemented in the control / command cabinets of the SSEE inverters.

[0014] With reference to [Fig.l], we designate by: - P cons gf the power setpoint imposed on the SSEE by the “grid forming” algorithm, which constitutes the input variable of the operating diagram; - f denotes the nominal frequency of the electrical network, which constitutes one of the regulation parameters. In France, f is generally set = 50Hz; - Kpf denotes the primary frequency adjustment gain, expressed in MW.Hz *, which is commonly called the primary adjustment energy; - f GF, which can be called “grid forming” frequency, is a variable extracted from correction block 1, as we will see in more detail later; - Pmes is the active power measured at the AC connection point of the inverter, low voltage side; - finally, ^gf designates the phase of the alternating voltage supplied by the inverter to the electrical network.

[0015] Pref denotes an intermediate variable of active power, which is expressed in the following form:

[0016] [Math.l]

[0017] The diagram in Figure 2 is simpler than that in Figure 1, from which it differs in that the algorithm now imposes a frequency setpoint, noted f GF- The correction block referenced C2 receives as input an intermediate variable of frequency / .,, and outputs the phase Oqf of the alternating voltage supplied by the inverter to the electrical network. The intermediate frequency variable / expresses itself under the shape :

[0018] [Math.2] f - f J ref J cons GF Kpj

[0019] These two schemes are equivalent in terms of performance and one can move from one to the other via the following equation:

[0020] [Math.3]

[0021] However, the difference between the “droop” and VSM algorithms lies in the structure of their corrector (blocks referenced C1 and C2 in figures 1 and 2).

[0022] Nevertheless, since this systematically integrates an integrator in the direct regulation chain, as will be seen in more detail later in this document, the “droop” and VSM algorithms have identical performances in stabilized mode and are therefore distinguished by their dynamic performances.

[0023] Since the beginning of the 2010s, the scientific community has focused its efforts on finding the most efficient algorithms, particularly in terms of angular stability, but also frequency behavior. However, there is no consensus to date: "droop" algorithms generally have better angular stability, but VSM algorithms reassure network managers thanks to their frequency behavior, which is similar to that of thermal production means.

[0024] A second problem, addressed more recently to the scientific community, concerns the operation of "grid forming" SSEEs when they arrive, following one or more network events, at the operating limit in active power, apparent power or AC current.

[0025] Indeed, this problem is often secondary in microgrid applications for which the SSEEs are generally oversized and rarely reach their limits. And when they do, a blackout is often an acceptable outcome, which is not the case in HTB island networks and in interconnected networks.

[0026] This question has only been addressed for a few years, and today there are a multitude of industrial solutions, and not all of them are satisfactory. This multitude of solutions leads to several problems.

[0027] From the investors' point of view first of all, it complicates the choice of a "grid forming" SSEE solution because: - the requirements in terms of grid forming algorithms depend on the requirements of the network manager and can therefore vary from one project to another; - the quality of the grid forming algorithm is not directly correlated to the cost of the SSEE grid forming solution, which sometimes requires choosing an expensive solution, for the sole purpose of having a grid forming algorithm compatible with the requirements of the network manager to which the project is to be connected.

[0028] From the point of view of network managers then, who may have to manage a network in which a set of industrial solutions with disparate performances coexist, which can weaken its stability. Summary

[0029] The present disclosure improves the situation.

[0030] A method is proposed for controlling at least one system forming a source of electrical energy and intended to be connected to an electrical network via an inverter controlled in voltage source mode according to a vector control algorithm for the amplitude and phase of the alternating voltage of the inverter, the vector control algorithm comprising a function for sharing the active power of the system supplied at the input by an active power or frequency setpoint, called the original vector control setpoint, and delivering at the output a phase of the alternating voltage.

[0031] Such a control method comprises: - a calculation of a modified vector control setpoint; - compensation of the original vector control setpoint from the modified vector control setpoint, delivering a vector control reference setpoint intended to supply the active power sharing function in place of the original setpoint.

[0032] According to another aspect, there is provided a device for controlling at least one system forming a source of electrical energy and intended to be connected to an electrical network via an inverter controlled in voltage source mode according to a vector control algorithm for the amplitude and phase of the alternating voltage of said inverter. Such a vector control algorithm comprises a function for sharing the active power of the system supplied at the input by an active power or frequency setpoint, called the original vector control setpoint, and delivering at the output a phase of the alternating voltage.

[0033] Such a control device comprises at least one processor configured to execute steps of: - calculation of a modified vector control setpoint; - compensation of the original vector control setpoint from the modified vector control setpoint, delivering a reference setpoint of vector control intended to supply the active power sharing function instead of the original setpoint.

[0034] According to another aspect, there is provided a computer program comprising instructions for implementing all or part of a method as defined herein when this program is executed by a processor. According to another aspect, there is provided a non-transitory, computer-readable recording medium on which such a program is recorded.

[0035] The features set out in the following paragraphs may, optionally, be implemented, independently of one another or in combination with one another:

[0036] The vector control algorithm is of the “grid forming” type.

[0037] The electrical energy source system is an electrical energy storage system, SSEE, by battery.

[0038] The vector control algorithm is a “droop” type algorithm and the calculation of the modified vector control setpoint implements a VSM type algorithm.

[0039] The vector control algorithm is a VSM type algorithm and the calculation of the modified vector control setpoint implements a limitation of a reference power determined from said original vector control setpoint.

[0040] Such a control method is implemented by an industrial automaton interfaced with said at least one electrical energy storage system, SSEE.

[0041] Such a control device is interfaced with one or more electrical energy storage system(s), SSEE, by battery, and is integrated into an industrial automaton forming an energy management system, PMS (for the English “Power Management System”). Brief description of the drawings

[0042] Other characteristics, details and advantages will appear on reading the detailed description below, and on analyzing the attached drawings, in which: Fig.l

[0043] [Fig.l] presents in the form of a block diagram a known algorithm for sharing the active power of a “grid forming” SSEE with an active power setpoint. Fig. 2

[0044] [Fig.2] presents in the form of a block diagram a known algorithm for sharing active power of a grid forming SSEE with a frequency setpoint. Fig. 3

[0045] [Fig.3] presents in synoptic form an example of an energy storage system electric, SSEE. Fig. 4

[0046] [Fig.4] shows a block diagram of a control method applied to the re regulation of active power, according to one embodiment. Fig. 5

[0047] [Fig.5] presents a schematic diagram of a control method applied to the re voltage / reactive power regulation, according to one embodiment. Fig. 6

[0048] [Fig.6] presents in the form of a block diagram a corresponding VSM algorithm to the performance required by an electricity network manager according to a first embodiment. Fig. 7

[0049] [Fig.7] details the operating principle of the corrector of the VSM algorithm of [Fig.5] according to this first embodiment. Fig. 8

[0050] [Fig.8] presents in the form of a block diagram an active power sharing algorithm “droop” of a “grid forming” SSEE implemented on the electrical network according to this first embodiment. Fig. 9

[0051] [Fig.9] illustrates the implementation of the control method according to this first mode of realization. Fig. 10

[0052] [Fig. 10] presents in the form of a block diagram an algorithm for sharing the equivalent active power obtained according to this first embodiment. Fig. 11

[0053] [Fig. 11] presents in the form of a block diagram an active power sharing algorithm VSM of a “grid forming” SSEE implemented in an electrical network according to a second embodiment. Fig. 12

[0054] [Fig. 12] illustrates the implementation of the control method according to this second embodiment, when the frequency of the SSEE is known. Fig. 13

[0055] [Fig. 13] illustrates the implementation of the control method according to this second embodiment, when the frequency of the SSEE is not known. Fig. 14

[0056] [Fig. 14] presents in the form of a block diagram an algorithm for sharing the equivalent active power obtained according to this second embodiment. Description of the embodiments

[0057] The general principle of the proposed control method is based on a control algorithm, implemented in an industrial automaton interfaced with one or more "grid forming" SSEEs, which calculates and sends at least one active power or electrical frequency setpoint, to the SSEE(s) with which it is interfaced. This control algorithm modifies the dynamic performances of the "grid forming" SSEEs seen by the network manager, in order to meet its requirements, but without modifying the "grid forming" algorithm, which is the property of the suppliers of the SSEE(s).

[0058] Reference is now made to [Fig. 3], which presents in block diagram form an example of an electrical energy storage system 10, SSEE or BESS (for the English “Battery Energy Storage System”). Such a BESS 10 comprises a plurality of devices 11;, four of which have been shown by way of example in [Fig. 3]. Each of these devices 111 to 114 comprises an electrical energy storage module, for example in the form of a pack of electrochemical battery cells, and a battery management system, also called BMS (for the English “Battery Management System”).

[0059] A bidirectional power flow P is established between the devices 111 to 114 and a conversion electronics module, or inverter 12, which allows the power supply of an electrical network to which the BESS 10 is connected.

[0060] The BESS 10 also comprises a control / command module 13, which sends control signals to the conversion electronics module 12, and receives from the latter voltage and flux intensity P measurement data. The control module 13 can also interrogate the BMS to receive from the latter estimated or calculated values ​​of charge level, SOC, temperature, or even charge / discharge current of the storage modules of the devices 111 to 114.

[0061] The control module 13 is in communication with a higher control stage 14, which controls the acquisition of data from the BESS 10, monitors its operation and commands it. This higher control stage 14 is for example controlled by the operator of the BESS 10, or an integrator of this battery storage system. It may be an industrial controller forming an energy management system, PMS, associated with several control modules 13. There is generally one PMS system per site, which is therefore interfaced with the BESS(s) present on the site.

[0062] The control method described in more detail below in relation to Figures 4 to 14 can be embedded in the PMS system, in the case where the operating algorithm of the PMS system is adapted by specific software development for integrate such a control method. It can also be implemented in a third-party industrial PLC interfaced with the BESS 10(s). It can also be implemented in an industrial PLC performing or receiving the result of the EMS (Energy Management System) function;

[0063] This choice allows flexibility in implementing the control algorithm in projects, since part of the operating software of this automaton is generally developed to measure for each project.

[0064] It will be noted that such a control method is also applicable to any energy source interfaced to the network by voltage inverters that can be controlled in "grid forming", such as wind turbines, photovoltaic panels, modules for producing electricity from hydrogen, etc. However, in the following, by way of example, we will endeavor to describe embodiments in which the energy source interfaced to the network by voltage inverters that can be controlled in "grid forming" is a battery-based electrical energy storage system, as illustrated schematically in [Fig.3].

[0065] [Fig.4] illustrates in block diagram form the control method according to one embodiment, applied to the active power regulation of an SSEE. An input variable of this control method is the original vector control setpoint of the “grid forming” algorithm of this SSEE, here an active power setpoint P cons- Such a control method is composed of two distinct parts: - a first block (1), which implements an algorithm for imposing on the SSEE a new “grid forming” reference, called modified vector control setpoint; - a second block (2), which implements a compensation algorithm for the reference of the existing “grid forming” algorithm, delivering as output a new setpoint, called vector control reference setpoint, which can be a power setpoint PC(ms gf or a frequency setpoint f GF-

[0066] It will be noted that, in the diagram of figure 4, the original vector control setpoint PCons could be replaced by a frequency setpoint fc ■ It will be noted, however, that, in the context of the control of the SSEE, the PMS function calculates an active power setpoint, so that the diagram of [Fig.4] is well suited to the implementation of the invention in an industrial automaton performing the PMS function.

[0067] In the event of loss of communication between the industrial automaton in which the control method according to one embodiment is implemented and the SSEE(s) with which it is interfaced, the SSEE(s) retain(s) the last setpoint values ​​transmitted by the automaton before the communication breaks down.

[0068] As illustrated by Figure 5, in one embodiment, such a method of control is also applicable for the voltage regulation of grid-forming SSEEs. The diagram in Figure 5 differs from that of Figure 4 by the nature of the input variable, namely the original vector control setpoint which can be a voltage setpoint Ucons or a reactive power setpoint Q, and by the vector control reference setpoint delivered at the output, which can be a grid-forming voltage reference setpoint Ucons GF or a grid-forming reactive power reference setpoint Q GF ■

[0069] It will also be noted that maximum performance of the control method according to one embodiment will be obtained if: - the measurements used in the SSEE “grid forming” algorithm are available for the PLC integrating such a control method (for example, the active power measured at the AC connection point of the inverter on the low voltage side Pmes) - Otherwise, they can be determined or approximated by calculation, as described below; - the sampling frequency and the precision of the variables of the automaton integrating such a control process are sufficient, taking into account the expected performance of the control process.

[0070] In the remainder of this document, we will focus more particularly on describing some examples of application to the active power sharing algorithm, within the framework of a battery-based electrical energy storage system controlled by “grid forming”.

[0071] Figures 6 to 10 concern a first example of modification of a “droop” algorithm into a VSM algorithm.

[0072] We consider a grid forming SSEE project on an electrical network in which the network manager's requirements require the use of the VSM algorithm, the general principle of which is illustrated in Figure 6. It receives as input a power setpoint PCons gf and delivers as output a phase 0GF of the alternating voltage of the inverter. The general principle of this VSM algorithm is similar to that presented previously in relation to Figure 1, the common elements of which will therefore not be described here in more detail. It differs by the presence of a saturation block, referenced 15, making it possible to limit the excursion range of the reference power Pref between two minimum values ​​Pmin and maximum Pmax. The values ​​of P min and Pmax are determined according to the sizing of the SSEE considered.Such a limitation of the excursion range is advantageous for protecting certain electrical networks, for example island networks, from a blackout, in limit cases of power delivered by the SSEE batteries, by allowing the electrical frequency of the SSEE to vary more widely to activate frequency load shedding or the activation of the clipping of renewable producers on overfrequency according to the . situation. This first example of implementation can therefore correspond, for example, to a project for the deployment of a battery-based SSEE in an island electricity network, for which the network manager needs the performance of a VSM-type “grid forming” algorithm as illustrated in [Fig.6].

[0073] Figure 7 illustrates in more detail the operation of the VSM corrector referenced 16. It receives as input the power difference variable — Pref PnieSf where Pmes is the active power measured at the AC connection point of the inverter on the low voltage side. In the case where this power is not known, it can be approximated from the active power measured for the entire SSEE system, which is divided by the number of inverters in the system.

[0074] The block referenced 17 corresponds to the simplified equation of a synchronous machine, which is characteristic of VSM regulation, and is based on Newton's second equation, where: - f denotes the nominal frequency of the electrical network, which constitutes one of the regulation parameters. For example f = 50Hz; - H denotes the inertia constant of the virtual machine; and - Sn represents the nominal apparent power.

[0075] The blocks referenced 18i and 182 are integrator blocks. The block referenced 19 implements any “damping” function p / f 1 allowing GF to be stabilized) the transfer function of the corrector 16 without generating a static error on the active power regulation. This can be, for example, a high-pass filter with a static gain, or a more complex form.

[0076] At the output of the corrector block 16 is delivered the phase 0GF of the alternating voltage of the inverter.

[0077] It is assumed, in this first example of implementation, that the industrial solution considered for this project, because it is less expensive, uses a “grid forming” algorithm of the “droop” type, as illustrated in [Fig.8].

[0078] This algorithm is based on a frequency instruction f GF, from which we deduce a frequency reference f — f _ , where, as previously, Pnies denotes the active power measured (or calculated) at the AC connection point of the inverter on the low voltage side, and Kpf denotes the primary frequency adjustment gain. This frequency reference fre. is filtered by a low-pass filter referenced 20, with time constant T. After integration by the integrator block referenced 21, the phase @gf of the AC voltage of the inverter is obtained at the output.

[0079] The industrial solution based on the algorithm of [Fig.8] is therefore not able to meet the requirements of the network manager, as illustrated in Figures 6 and 7.

[0080] Figure 9 schematically illustrates the solution proposed in the context of this first embodiment, which makes it possible to overcome this problem. The block referenced IA makes it possible to calculate a modified setpoint, noted / GF, which is a frequency setpoint: this block referenced IA therefore makes it possible to impose a new reference to the SSEE. The block referenced 2A allows the compensation of the SSEE reference, by transforming the modified setpoint GF into a new setpoint f crn<. GF, constituting the reference setpoint intended to supply the active power sharing function in place of the original setpoint f GF constituting the input variable of the algorithm of [Fig.8].

[0081] The modified setpoint GF is obtained, from an active power setpoint Pcons gf, by implementing a VSM type algorithm illustrated in Figures 6 and 7.

[0082] We thus obtain the equivalent performances illustrated by the block diagram of figure 10, which are therefore compatible with the requirements of the network manager. It will be noted that we consider, at the input of the low-pass filter referenced 20, that / GF « Jref> due to the possible delay which may appear between the system realizing the calculation of the new vector control reference setpoint according to this embodiment, and the automaton implementing the “droop” type algorithm of [Fig.8]. This delay may in particular depend on the sampling frequency of the PMS system.

[0083] A parameterization of the time constant T of the low-pass filter 20 is preferably chosen to be as low as possible so that the dynamics of the filter in the existing “grid forming” solution is negligible compared to the overall dynamics of the complete solution illustrated in [Fig. 10].

[0084] A second example embodiment is now presented in relation to Figures 11 to 14. We consider the same situation as in the first example embodiment, for example a project within the framework of an island network, for which the performance requirements of the network manager require the use of the VSM algorithm of Figures 6 and 7. However, we now consider that the industrial solution anticipated for this project uses a VSM-type active power sharing algorithm of a “grid forming” SSEE as illustrated in [Fig. 11].

[0085] As will be noted, the VSM algorithm of [Fig.l 1] differs from the VSM algorithm of [Fig.6] in that it does not include a saturation block referenced 15 to limit the power excursion range between Pmin and Pmax. The algorithm of the anticipated industrial solution is therefore already close to the algorithm required by the ges network operator, but does not allow the desired frequency behavior of the grid forming inverter to be obtained.

[0086] In this second exemplary embodiment, two implementations are possible, depending on the availability or not of the frequency signal of the SSEE for the automaton in which the claimed control method is implemented.

[0087] [Fig. 12] illustrates the implementation of the claimed control method in the case where the frequency signal of the SSEE is available. The block referenced IB implements an algorithm for imposing a new vector control setpoint on the system, and the block referenced IC implements an algorithm for compensating the original vector control setpoint.

[0088] Figure 13 illustrates the implementation of the claimed control method in the case where the frequency signal of the SSEE is not known to the automaton implementing the control method. In this case, it is necessary to recalculate this frequency signal, hence a block referenced IC more complex than the block referenced 1B of Figure 12. The upper part of the block IC corresponds substantially to a reproduction of the “grid forming” algorithm, making it possible to calculate the inverter frequency GF, used as an input variable of the block IC carrying out the calculation of a modified vector control setpoint, making it possible to impose a new control setpoint on the system. The compensation block of the SSEE IC reference is identical to the block IB of [Fig. 12].

[0089] It will be noted that as a variant, in a sub-optimal mode, it would also be possible to measure this GF inverter frequency by means of a SSEE measuring unit.

[0090] In the case of Figure 12, we obtain the equivalent performances illustrated in Figure 14, which are compatible with the requirements of the network manager, for the active power sharing algorithm. It will be noted that we assume, at the output of the saturation block referenced 15 that Pref gf ~ Pref: this approximation reflects the delay which may appear at the transition between the system implementing the algorithm of [Fig.12] and the system implementing the algorithm of [Fig.11], and which depends on the sampling frequency of the industrial controller, for example the PMS, implementing the claimed control method. Industrial application

[0091] These technical solutions can be applied in particular to all SSEE “grid forming” solutions, which they make compatible with the majority of network managers’ requirements. List of reference signs

[0092] - Cl: Corrector; - C2: Corrector; - 1, IA, IB, IC: block of imposition at the SSEE of a new “grid forming” reference; - 2, 2A, 2B, 2C: compensation block for the SSEE “grid forming” setpoint; - 10: Electrical energy storage system, SSEE or BESS; - 1C: Electrical energy storage device; - 12: conversion electronics module, or inverter; - 13: control / command module; - 14: upper control floor; - 15: saturation block; - 16: VSM corrector; - 17: VSM regulation block; - 18; : integrator block; - 19: damping function; - 20: low-pass filter; - 21: integrator block;

Claims

Claims

1. Method for controlling at least one system (10) forming a source of electrical energy and intended to be connected to an electrical network via an inverter (12) controlled in voltage source mode according to a vector control algorithm for the amplitude and phase of the alternating voltage of said inverter, said vector control algorithm comprising an active power sharing function of said system supplied at the input by an active power or frequency setpoint, called the original vector control setpoint, and delivering at the output a phase of said alternating voltage, characterized in that it comprises: - a calculation (1, IA, IB, IC) of a modified vector control setpoint;- a compensation (2, 2A, 2B, 2C) of the original vector control setpoint from said modified vector control setpoint, delivering a vector control reference setpoint intended to supply said active power sharing function in place of said original setpoint.;

2. Control method according to claim 1, characterized in that said vector control algorithm is of the “grid forming” type.

3. Control method according to any one of claims 1 and 2, characterized in that said system forming an electrical energy source is an electrical energy storage system, SSEE, by battery.

4. Control method according to any one of claims 1 to 3, characterized in that said vector control algorithm is a “droop” type algorithm and the calculation of the modified vector control setpoint implements a VSM type algorithm.

5. Control method according to any one of claims 1 to 3, characterized in that said vector control algorithm is a VSM type algorithm and the calculation of the modified vector control setpoint implements a limitation (15) of a reference power determined from said original vector control setpoint.

6. Control method according to any one of claims 1 to 5, characterized in that it is implemented by an industrial automaton (14) interfaced with said at least one energy storage system. electric, SSEE.

7. Device for controlling at least one system (10) forming a source of electrical energy and intended to be connected to an electrical network via an inverter (12) controlled in voltage source mode according to a vector control algorithm for the amplitude and phase of the alternating voltage of said inverter, said vector control algorithm comprising an active power sharing function of said system supplied at the input by an active power or frequency setpoint, called the original vector control setpoint, and delivering at the output a phase of said alternating voltage, characterized in that it comprises at least one processor configured to execute steps of: - calculation (1, IA, IB, IC) of a modified vector control setpoint;- compensation (2, 2A, 2B, 2C) of the original vector control setpoint from said modified vector control setpoint, delivering a vector control reference setpoint intended to supply said active power sharing function in place of said original setpoint.;

8. Control device according to claim 7, characterized in that it is interfaced with one or more electrical energy storage system(s) (10), SSEE, by battery, and in that it is integrated into an industrial automaton (14) forming an energy management system, PMS (for the English “Power Management System”).

9. Computer program comprising instructions for implementing the method according to one of claims 1 to 6 when this program is executed by a processor.

10. Non-transitory recording medium readable by a computer on which is recorded a program for implementing the method according to one of claims 1 to 6 when this program is executed by a processor.

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