Electrical architecture comprising a linear photovoltaic installation consisting of several groups of photovoltaic panels and a direct current (DC) network, connected to an alternating current (AC) transmission and / or distribution network with possible transmission of power from the AC network via the DC network.

Abstract

An electrical architecture comprising a linear photovoltaic installation consisting of several groups of photovoltaic panels and a direct current (DC) network, connected to an alternating current (AC) transmission and / or distribution network, with the possibility of power being transmitted from the AC network via the DC network. The invention essentially consists of implementing an architecture with at least one linear PV installation connected to a DC network and interconnecting this sub-assembly at at least two distinct interconnection points with a preferably existing AC electrical network. Each interconnection point to a node of the AC network is a voltage source converter (VSC) capable of injecting from 0 to 100% of the maximum power P of the linear PV installations. Figure for the abstract: Fig. 2

Description

Title of the invention: Electrical architecture comprising a linear photovoltaic installation made up of several groups of photovoltaic panels and a direct current (DC) network, connected to an alternating current (AC) transmission and / or distribution network with possible transmission of the power from the AC network by the network DC. Technical field

[0001] The present invention relates to the general field of electrical networks.

[0002] The invention relates more particularly to the interconnection between an alternating current (AC) transport and / or distribution network and a linear photovoltaic installation.

[0003] By "linear PV installation" is meant here and within the scope of the invention, photovoltaic panels arranged in groups along a surface which extends mainly along a line and preferably on or along ground already built / developed by man, such as cycle paths, highway edges, railway lines, etc. or natural, for example not usable for agricultural purposes.

[0004] By "system services" is meant here and within the scope of the invention, the solutions which thus ensure the permanent balance between production and electricity consumption. Thus, system services are necessary services for any network manager and make it possible to ensure reliable, stable and efficient operation of the electricity network.

[0005] Throughout the application the following acronyms are used for simplicity:

[0006] AC: Anglo-Saxon acronym for “Alternative Current” which designates alternating current (AC);

[0007] DC: Anglo-Saxon acronym for “Direct Current” which designates direct current (DC);

[0008] MVDC: Anglo-Saxon acronym for “Medium Voltage Direct Current” which designates medium voltage direct current, typically in the range of 30 to 150 kilo volts (kV);

[0009] HVDC: Anglo-Saxon acronym for “High Voltage Direct Current” which designates high voltage direct current, typically above 150 kilo volts (kV);

[0010] VSC: Anglo-Saxon acronym for “Voltage Source Converter” which designates a converter operating as a voltage source;

[0011] MMC: Anglo-Saxon acronym for “Modular Multi-Level Converter” which designates a converter with multi-stage modules. Prior art

[0012] The context of high demand for renewable energy (RE) with the need for a dedicated electricity network, typically up to 30% in 2030 in France and expansion of the share of solar in RE, requires the installation of numerous ground-based photovoltaic (PV) solar power plants, with large powers, typically of the order of a few hundred MW each.

[0013] The question of land available for this PV technology therefore becomes crucial. Indeed, given the surface area required, the deployment of large ground-mounted PV solar power plants can create conflicts of use with agricultural land and affect biodiversity. For example, the most powerful PV solar power plant in France to date, with a capacity of 300 MW, is located in Cestas, near Bordeaux, on 260 hectares.

[0014] Finding new land to develop PV solar power plant projects has therefore become the main concern of renewable energy developers.

[0015] Furthermore, given the desire of public authorities to limit the use of large agricultural areas for the construction of such ground-based PV power plants, ecologically acceptable alternatives must be found.

[0016] A solution that addresses this problem consists of taking advantage of so-called linear surfaces, in the form of land already developed / constructed by man, such as cycle paths, highway edges, railways... or natural surfaces, not usable for agricultural purposes, such as along waterways and which extend over tens, even hundreds of kilometers, to install high-power PV systems. These potential surfaces have the advantage of already being very present, directly exploitable as is to install PV panels and inexpensive since they do not require the acquisition of land.

[0017] The implementation of new types of linear PV installations / power plants will therefore open up new opportunities in the PV development strategy. There are already a few linear PV installation projects in the world, but these are a priori of small power, typically a few kW. In addition, very few articles on the design of these linear PV installations have been published.

[0018] However, moving from PV power plants occupying tens or hundreds of hectares to linear PV installations extending over tens of hectometres or kilometres requires rethinking the entire architecture of the related electricity network.

[0019] Generally speaking, the European Union's strategies for the development of large-scale renewable energy sources highlight the important roles of electrical infrastructure and sector coupling, i.e. the interconnection between gas and electricity, to achieve deep decarbonization of the economy.

[0020] There is therefore a need to propose an optimized technical solution for electrical architecture which allows the massive connection of linear PV installations to the existing electrical infrastructure, while providing services going beyond the simple injection of PV production.

[0021] The aim of the invention is therefore to respond at least in part to this need. Statement of the invention

[0022] To do this, the invention relates, in one of its aspects, to an electrical architecture comprising:

[0023] - at least one linear installation comprising at least one group of panels photovoltaic (PV), suitable for producing a maximum total power P, and

[0024] a direct current (DC) network comprising at least one bus to which the group(s) of PV panels are connected in electrical parallel via each of a DC / DC converter,

[0025] - an alternative transport and / or distribution network (AC),

[0026] - at least two voltage source converters (VSC); one of the two converters weavers connecting the DC bus to a first node of the AC network, the other of the two converters connecting the DC bus to a second node of the AC network, distinct from the first node, each of the VSC converters being adapted to inject from 0 to a value greater than 100% of the power P into the AC network, at least one of the converters being bidirectional,

[0027] - a control system adapted to determine the power to be transported between the DC network from the VSC converters and the AC network, depending on the needs and / or operating regimes of the latter.

[0028] Advantageously, the VSC converters are modular multilevel converters (MMC) and / or bidirectional and / or sized to ensure the absorption of the power portion of the AC network.

[0029] The possible control modes of VSC converters are:

[0030] - Vac / f: Control of the voltage at the connection point and the frequency of the AC network - Vac-phi: Control of the voltage at the AC network connection point and the phase shift - Vdc-phi: Control of the DC bus voltage and phase shift - Vdc-Q: Control of DC bus voltage and reactive power - PWM-phi: Control of the PWM modulation of the VSC inverter and the phase shift - P-Vac: Control of injected power and voltage at the AC network connection point - PQ: Control of active and reactive power injected into the AC network - Vdc-Vac: Control of the DC bus voltage and the voltage at the connected point of the AC network - P-cos(f): Control of active power injected into the AC network and of the power factor - Vdc-cos(f): Control of the DC bus voltage and the power factor...

[0031] Among all these control modes, the control modes PQ; P-Vac; Vac / f; Vdc-Q are preferred for the transport and services function according to the invention.

[0032] According to an advantageous embodiment, the DC network of the linear installation comprises at least one high voltage direct current (HVDC) bus connected to the medium voltage direct current (MVDC) bus and to a voltage source converter (VSC) connected to a node of the AC network.

[0033] According to another advantageous embodiment, the DC network absorbs at one of the first or second nodes, at least part of the power of the AC network in the event of failure of the latter between the first and the second nodes, for example in the event of loss of an AC line.

[0034] Advantageously, the VSC converters are modular multilevel converters (MMC) and / or bidirectional and / or sized to ensure the absorption of the power portion of the AC network.

[0035] According to another advantageous embodiment, the bus to which the groups of PV panels are directly connected in electrical parallel is a medium voltage direct current (MVDC) bus.

[0036] The MVDC bus can advantageously be connected to the AC distribution network and / or AC transmission network.

[0037] According to an advantageous variant, the DC network of the linear PV installation comprises a high voltage direct current (HVDC) bus connected only to the AC transmission network.

[0038] Advantageously, the VSC converters are modular multilevel converters (MMC).

[0039] According to an advantageous configuration, the bus to which the group(s) of PV panels are directly connected in electrical parallel is a medium voltage direct current (MVDC) bus.

[0040] According to an advantageous embodiment variant, the architecture comprises several geographically distributed loads, such as high-power electric vehicle charging stations or electrolysers for powering hydrogen-powered vehicles, each connected via a DC / DC converter. DC to MVDC bus.

[0041] According to another advantageous embodiment variant, the architecture comprises several geographically distributed electrical storage means, such as batteries, each connected via a DC / DC converter to the MVDC bus.

[0042] According to another advantageous embodiment variant, the architecture comprises other geographically distributed current sources, such as wind turbines, each connected via a DC / DC converter to the MVDC bus.

[0043] According to an advantageous embodiment, the DC network of the linear PV installation comprises at least one high voltage direct current (HVDC) bus, connected to the medium voltage direct current (MVDC) bus and to a voltage source converter (VSC) connected to a node of the AC network.

[0044] The control system can advantageously be connected to the real-time control and data acquisition (SCADA) system of the AC network. This makes it possible to differentiate the power to be absorbed by one or the other of the at least two injection nodes.

[0045] According to another advantageous embodiment, the architecture comprises means for measuring voltage and / or frequency at the first and second nodes, connected to the control system so that it determines the power between the power to be transported between the DC network from the VSC converters and the AC network as a function of the measurements made.

[0046] Thus, the invention essentially consists of setting up a linear PV system, comprising groups of PV panels and a DC network, and interconnecting this subassembly at at least two interconnection points with a preferably existing AC electrical network. Each interconnection point at a node of the AC network is a VSC voltage source converter which can recover power from the AC network to have it transported by the DC network.

[0047] The invention therefore consists of distributing the power to be transported between the DC network from the VSC converters and the AC network, according to the needs and / or operating regimes of the latter.

[0048] According to an advantageous configuration, the DC network absorbs at least part of the power of the AC network in the event of failure of the latter, for example in the event of loss of a line.

[0049] Unlike a state-of-the-art PV power plant which is located at a specific point on the electrical network and therefore capable of injecting only at this point, the architecture according to the invention with a linear PV installation distributed over a large geographical area allows interconnection at several distant points on the electrical network.

[0050] The architecture according to the invention makes it possible to maintain and increase reliability and a

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[0060] high resilience of the existing electricity network while expanding its capacity to integrate large quantities of renewable energy (RE) in the future through linear PV installations. Ultimately, an architecture according to the invention has many advantages, including: - due to the choice of linear installations, a considerable reduction in land occupation as well as a reduction in the construction of HVAC lines; an increase in the penetration capacity of PV systems into the existing AC electricity grid; a reduction in PV production variation due to intermittency thanks to the aggregation of linear installations over a long distance; - improving network flexibility, through the possibility of exchanging energy in both directions between a DC network and an AC network; - high reliability and resilience; - an improvement in the stability of the AC network; - the possibility of maintaining continuity of service in the event of a fault or separation of the AC network; - a simplification of energy management; - ease of connecting DC systems such as storage and / or high-power fast charging stations for electric vehicles and / or electrolysers and fuel cells to the DC network of linear installations; - the possibility of coupling with offshore or onshore wind farms... - the possibility of effective protection between an AC network and a DC network; - the reduction of total losses of the AC network by the optimal distribution of power. Other advantages and characteristics of the invention will become more apparent upon reading the detailed description of examples of implementation of the invention given by way of illustration and not limitation with reference to the following figures. Brief description of the drawings [Fig.l] [Fig.l] schematically illustrates an electrical architecture according to the invention as it could be implemented in the south-eastern region of France. [Fig.2] [Fig.2] is a synoptic view of the electrical architecture according to the invention. [Fig.3] [Fig.3] is a schematic view of the “New-England IEEE 39 nodes” test network on which the DC network power injection tests according to the architecture electrical tests of the invention have been carried out.

[0061] [Fig.4A], [Fig.4B] [Fig.4A] and 4B illustrate the power distributions on lines of the New England network and two VSC converters of a DC network with six linear PV installations connected to the New England network, following a line loss test.

[0062] [Fig.5],[Fig.6],[Fig.7] Figures 5, 6, 7 respectively illustrate the variation of rotor angle power and speed of generators (synchronous machines) of the New England network without the architecture according to the invention, following a short-circuit test.

[0063] [Fig.8], [Fig.9] Figures 8 and 9 illustrate respectively the variation of voltage at a node and of frequency of the New-England network without the architecture according to the invention, following the short-circuit test.

[0064] [Fig. 10] [Fig. 10] illustrates the variation of power and reactive power at the two VSC converters of the architecture according to the invention with the New England network and according to a first configuration of differentiated power injection at the two VSCs, following a short-circuit test.

[0065] [Fig.11], [Fig.12], [Fig.13] Figures 11, 12, 13 illustrate respectively the variation in power of the rotor angle and speed of the generators (synchronous machines) of the New-England network with the architecture according to the invention and according to the first configuration of differentiated power injection to the two VSC converters, following the short-circuit test.

[0066] [Fig. 14], [Fig. 15] Figures 14 and 15 respectively illustrate the variation of voltage at a node and of frequency of the New-England network with the architecture according to the invention and according to the first configuration of differentiated power injection to the two VSC converters, following the short-circuit test.

[0067] [Fig. 16] illustrates the power variation at the two VSC converters of the architecture according to the invention with the New England network and according to a second configuration of differentiated power injection at the two VSCs, following a short-circuit test.

[0068] [Fig.17], [Fig.18], [Fig.19] Figures 17, 18, 19 illustrate respectively the variation in power of the rotor angle and speed of the generators (synchronous machines) of the New England network with the architecture according to the invention and according to the second configuration of differentiated power injection to the two VSC converters, following the short-circuit test.

[0069] [Fig.20], [Fig.21] Figures 20 and 21 respectively illustrate the variation of voltage at a node and of frequency of the New-England network with the architecture according to the invention and according to the second configuration of differentiated power injection to the two VSC converters, following the short-circuit test. Detailed description

[0070] [Fig.l] shows an architecture according to the invention as it could be implemented in the south-eastern region of France.

[0071] As illustrated, this electrical architecture comprises a plurality 1 of groups of photovoltaic (PV) panels 10, adapted to produce a maximum total power P. These groups of panels 10 are distributed over hundreds of kilometers in this region by being arranged on elongated ground surfaces on land already built by man, such as along railway edges, highways, etc.

[0072] All these groups of panels are connected in electrical parallel by at least one bus 20, 21 of a direct current (DC) network, to form a single linear PV installation. This linear PV installation is itself connected to the transmission network 3 and / or distribution network 4 already existing in this region. All the groups of PV panels are therefore connected to each other by at least one DC bus 20, 21.

[0073] [Fig.2] shows in more detail the components and possible connection modes according to one embodiment of such an architecture.

[0074] In this [Fig.2], the groups of PV panels are distributed along a line L on the ground. The plurality 1 of these PV groups can produce a maximum total power P.

[0075] The linear PV installation comprises the plurality of groups of panels as well as the DC network 2, which here comprises several MVDC buses 20 to which the linear installations 10 are connected in electrical parallel, each via a DC / DC converter 11.

[0076] The DC network also includes several HVDC buses 21 each connected to one or more of the MVDC buses 20. The HVDC buses 21 can carry direct current throughout the DC network.

[0077] Each MVDC bus 20 or HVDC bus 21 is connected to a node of an AC transmission network 3 or to that of an AC distribution network via a voltage source converter 22. At least one of the converters is bidirectional, to allow power to pass from the AC network to the DC network.

[0078] Preferably, the VSC converters 22 are modular multilevel converters (MMC).

[0079] Each of the VSC converters 22 is adapted to inject from 0 to 100% of the power P into the AC network. At least one of the converters is adapted to inject more than 100% of the power P into the AC network.

[0080] According to the invention, the architecture control system is adapted to distribute the power to be transported between the DC network from the VSC converters 22 and the AC network, depending on the needs and / or operating regimes of the latter.

[0081] The control system may be integrated with the real-time supervisory control and data acquisition (SCADA) system of the AC network.

[0082] In an advantageous configuration, the DC network absorbs at least part of the power of the AC network in the event of a failure of the latter, for example in the event of loss of an AC line. In other words, the DC network of the linear PV installation makes it possible to avoid network congestion.

[0083] Furthermore, the control system allows the electrical architecture to contribute at least part of the system services of the AC network through the DC network of the linear PV installation.

[0084] In the context of the invention, the system services can be summarized as follows:

[0085] - SI: frequency adjustment (management of active power reserves, primary adjustment, secondary adjustment and tertiary frequency adjustment); - S2: voltage adjustment; - S3: improvement of network stability (frequency, voltage and rotor or angular angle of synchronous machines) and reduction of power oscillations; - S4: short-circuit support capacity as a firewall and increased resilience of the AC power grid; - S5: congestion management by power transit control; - S6: compensation for transport losses by the optimal distribution of power ; - S7: autonomous start (“black start” in Anglo-Saxon language); - S8: non-synchronous coupling of the electrical zones, which makes it possible to create a coupling between two networks operating at different frequencies, for example at 50Hz and 60Hz; - S9: fast charging of electric vehicles along the DC network.

[0086] As also illustrated in this [Fig.2], the DC network of the architecture several geographically distributed loads, such as high-power electric vehicle (EV) charging stations or electrolyzers (H2) for hydrogen vehicles. Each of these loads is connected directly to the MVDC bus 20 via a DC / DC converter 23.

[0087] The DC network can also support several geographically distributed electrical storage means, such as batteries. Each storage means is also directly connected to the MVDC bus 20 via a DC / DC converter 23.

[0088] Validations of the architecture proposed according to the invention were carried out on the IEEE New-England 39-node test transport AC network. This AC network, shown diagrammatically in [Fig.3], is a simplification of the New England network in the northeastern United States. It has 39 nodes (numbered 30 to 39), including 10 generation nodes and 46 lines. The generators at the generation nodes are referenced G1 to G10. In particular, at node 29, there is a generator G9.

[0089] The total production and consumption of the New-England AC network are respectively 6147 MW and 6097 MW.

[0090] The validations carried out on this New-England network are done with the software marketed under the name “Powerfactory” by the company Digsilent.

[0091] The validation test hypotheses are made by considering a number of six groups of PV panels all connected in electrical parallel to a DC bus within a linear PV installation. The maximum power of each PV group is 50 MW, i.e. a maximum total power P of 300 MW.

[0092] The DC bus is connected to two VSC converters which are connected to the New-England AC network at nodes 26 and 29, referenced VSC_26 and VSC_29 respectively.

[0093] In other words, in tests A / and B / below, these two VSC converters, VSC_26 and VSC_29, ensure the injection of production from the six PV groups into the New-England AC network.

[0094] The block diagram of the test configuration is shown in [Fig.3].

[0095] And, for comparison, in tests A / and B / we consider the New-England AC network without DC network, i.e. without any linear PV installation or VSC converter at the nodes.

[0096] A / Congestion test

[0097] In this test, the loss of a line of the AC network is simulated, between nodes 28 and 29, then the different powers are observed respectively on the one hand on the lines of the AC network between nodes 26 and 28 and between nodes 28 and 29 and on the other hand at the converters VSC_26 and VSC_29.

[0098] This simulation is illustrated on the curves of figures 4A and 4B which show the different successive phases of the test:

[0099] i / Before the loss of the line between nodes 28 and 29, the power transit on the AC network is 275 MW on the line between nodes 28 and 29 and 174 MW on the line between nodes 26 and 29.

[0100] The power at converters VSC26 and VSC29 is 291 MW and 0 MW, respectively.

[0101] ii / The loss of the line between nodes 28 and 29 is triggered after a time t equal to 30s.

[0102] iii / After the loss of this line between nodes 28 and 29, the power transit on the AC network is 0 MW on the line between nodes 28 and 29 and 322 MW on the line between nodes 26 and 29.

[0103] The power at converters VSC_26 and VSC_29 is 408 and 128 MW, respectively.

[0104] For comparison, without the presence of the PV groups and the converters VSC_26 and VSC_29, the power transit on the line between nodes 26 and 29 is 450 MW. There is an overload on this line of the AC network.

[0105] It therefore appears that with the presence of the PV groups and the converters VSC_26 and VSC_29, the power transit is distributed between the line between nodes 26 and 29 (322 MW) and the DC network of the linear PV installation (128 MW).

[0106] Therefore, the DC network of the linear PV installation absorbs a significant portion of power. And the congestion of the AC network is avoided (S5).

[0107] B / Stability test

[0108] The test here consists of a short circuit to study the resistance capacity of the linear PV installation, and therefore its influence on the stability of the AC network.

[0109] At time t equal to 1.5 s, the appearance of a short circuit on node 28 is simulated, which is eliminated at t equal to 1.7 s, i.e. 200 ms after its appearance.

[0110] Bl / Without the presence of a linear PV installation and the VSC_26 and VSC_29 converters, we note that the AC network becomes unstable as soon as the short circuit appears.

[0111] Indeed, as shown in [Fig.5], which illustrates the temporal variation of the power of the generators (synchronous machines), there is a significant oscillation of the power of all the generators G1 to G10.

[0112] For machine G9, we also observe a loss of angular stability ([Fig.6]), a loss of synchronization following an increase in speed ([Fig.7]) because G9 is very close to the short-circuit point (node ​​26).

[0113] The AC network loses voltage and frequency stability, as illustrated respectively in [Fig.8] which shows the voltage variation in reduced unit (pu) at node 28 and in [Fig.9] which illustrates the frequency variation in reduced unit (pu).

[0114] B2 / Here we consider the DC network of the linear PV installation, with the six groups PV, which injects power with a distribution of 200 MW on VSC_26 connected to node 26 and 100 MW on VSC_29 connected to node 29.

[0115] [Fig. 10] illustrates the variation of active and reactive powers of VSC_26 connected to node 26 and VSC_29 connected to node 29.

[0116] We therefore note that in the event of a short circuit, the network is kept stable, thanks to the very efficient control system, via the two converters VSC_26 and VSC_29. This test case B2 / shows the very good resistance capacity of the linear PV installation in the event of a short circuit to the AC network (S4). The converter VSC_26 is very impacted by the short circuit because it is close to node 26 where the short-circuit point is. The converter VSC_26 participates very actively in providing reactive power to raise the voltage at the connection node. After the short circuit, the two converters VSC_26 and VSC_29 are working normally.

[0117] Figures 11, 12, 13 illustrate respectively in this test case B2 / , the variation of power of the generators, of the rotor angle and of the speed of the synchronous machines.

[0118] The rotor angle as well as the speed of the synchronous machines G1 to G10 are therefore stabilized.

[0119] Voltage stability ([Fig. 14]) and frequency stability ([Fig. 15]) are also observed. The service (S3) is therefore provided by the DC network of the linear installation, through their contribution to the frequency (SI) and voltage (S2) adjustment.

[0120] B3 / Here we consider the DC network of a linear PV installation with the six groups PV, which injects power with a distribution of 300 MW on VSC_26 connected to node 26 and 0 MW on VSC_29 connected to node 29.

[0121] [Fig. 16] illustrates the variation of active powers of VSC_26 connected to node 26 and VSC_29 connected to node 29.

[0122] We therefore note that in the event of a short circuit, the network is kept stable, thanks to the very efficient control system, via the two converters VSC_26 and VSC_29. This test case B3 / shows the very good resistance capacity of the linear PV installations in the event of a short circuit to the AC network (S4). The VSC_26 converter is very impacted by the short circuit because it is close to node 26 where the short circuit point is. The VSC_26 converter participates very actively in providing reactive power to raise the voltage at the connection node. After the short circuit, the two converters VSC_26 and VSC_29 operate normally.

[0123] Figures 17, 18, 19 illustrate respectively in this test case B3 / , the variation of power of the generators, of the rotor angle and of the speed of the synchronous machines.

[0124] The rotor angle as well as the speed of the synchronous machines G1 to G10 are therefore stabilized.

[0125] Voltage stability ([Fig.20]) and frequency stability ([Fig.21]) are also observed. The service (S3) is therefore provided by the DC network of the linear PV installation, through their contribution to the frequency (SI) and voltage (S2) adjustment.

[0126] The results of tests B2 / and B3 / show the support capacity of the linear PV installation, whatever the differentiated powers injected into the VSC converters, to attenuate oscillations in the face of disturbances, in the event of a short circuit.

[0127] The invention is not limited to the examples which have just been described; it is possible in particular to combine characteristics of the examples illustrated within non-illustrated variants.

[0128] Other variants and embodiments may be envisaged without departing from the scope of the invention. List of cited references

[0129] [1]: T. Athay, R. Podmore, and S. Virmani. “A Practical Methodfor the Direct Analysis ofTransient Stability”. In: IEEE Transactions on Power Apparatus and Systems PAS-98 (2 Mar. 1979), pp. 573-584.

[0130] [2]: M. A. Pai. “Energy function analysis for power System stability”. The Kluwer in ternational sériés in engineering and computer science. Power electronics and power Systems. Boston: Kluwer Academie Publishers, 1989.

Claims

Claims

1. Electrical architecture comprising: - at least one linear installation comprising at least one group of photovoltaic (PV) panels (10) adapted to produce a maximum total power P, and a direct current (DC) network (2) comprising at least one bus (20, 21) to which the group(s) of PV panels are connected in electrical parallel via each of a DC / DC converter (11), - an alternating current (AC) transmission (3) and / or distribution (4) network, - at least two voltage source converters (22) (VSC), one of the two converters connecting the DC bus to a first node of the AC network, the other of the two converters connecting the DC bus to a second node of the AC network, distinct from the first node, each of the VSC converters being adapted to inject from 0 to a value greater than 100% of the power P into the AC network,at least one of the converters being bidirectional - a control system adapted to determine the power to be transported between the DC network from the VSC converters and the AC network, depending on the needs and / or operating regimes of the latter.,

2. Architecture according to claim 1, the DC network of the linear PV installation comprising at least one high voltage direct current (HVDC) bus, and connected to the medium voltage direct current (MVDC) bus and to a voltage source converter (22) (VSC) connected to a node of the AC network.

3. Architecture according to claim 1 or 2, the DC network absorbing at one of the first or second nodes, at least part of the power of the AC network in the event of failure of the latter between the first and second nodes, for example in the event of loss of an AC line.

4. Architecture according to claim 3, the VSC converters being modular multilevel converters (MMC) and / or bidirectional and / or sized to ensure the absorption of the power part of the AC network.

5. Architecture according to one of the preceding claims, the converters being controlled according to a mode of control of injected power and of the voltage at the point of connection of the network (P-Vac: AC) or according to a mode of control of active and reactive power injected into the AC network (PQ) or according to a mode of control of the DC bus voltage and reactive power (Vdc-Q) or according to a mode of control of the voltage at the connection point and the frequency of the AC network (Vac / f).

6. Architecture according to one of the preceding claims, the bus (20) to which the groups of PV panels are directly connected in electrical parallel being a medium voltage direct current (MVDC) bus.

7. Architecture according to claim 6, the MVDC bus being connected to the AC distribution network and / or AC transmission network.

8. Architecture according to one of the preceding claims, the DC network of the linear PV installation comprising a high voltage direct current (HVDC) bus and connected only to the AC transmission network.

9. Architecture according to one of the preceding claims, comprising several geographically distributed loads, such as high-power electric vehicle charging stations or electrolyzers for powering hydrogen-powered vehicles, each connected via a DC / DC converter (23) to the MVDC bus.

10. Architecture according to one of claims 5 to 9, comprising several geographically distributed electrical storage means, such as batteries, each connected via a DC / DC converter (23) to the MVDC bus.

11. Architecture according to one of claims 5 to 10, comprising other geographically distributed current sources, such as wind turbines, each connected via a DC / DC converter (23) to the MVDC bus.

12. Architecture according to one of the preceding claims, the system being connected to the real-time control and data acquisition (SCADA) system of the AC network.

13. Architecture according to one of the preceding claims, comprising means for measuring voltage and / or frequency at the first and second nodes, connected to the control system so that it distributes the power to be transported between the DC network from the VSC converters and the AC network according to the measurements carried out.

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