Electric Vehicle Ultra-Fast Battery Chargers: A Boost for Power System Stability?

As a consequence of the exponential growth of the electric vehicle (EV) market, DC fast-charging infrastructure is being rapidly deployed all around the world. Ultra-fast charging (UFC) stations are starting to pose serious challenges to the electric power system operation, mostly due to their high peak power demand and unregulated discontinuous operation. To address these issues, local energy storage can be installed, ensuring a smoother grid power absorption profile and allowing to provide grid-supporting features. In this work, a control solution for the grid-side AC/DC converter of next-generation EV UFC stations is proposed. A virtual synchronous compensator (VSC) control algorithm is implemented, in order to lessen the impact of the charging station on the utility and to provide the full spectrum of grid ancillary services (i.e., frequency regulation, reactive power compensation, harmonic reduction, short circuit current generation, etc.). The proposed control strategy is verified experimentally on a downscaled 15 kVA three-phase inverter, emulating the grid front-end of the charging station.


Introduction
Despite the constantly increasing performance and energy density of Li-ion batteries, their cost and weight still poses a major limit to electric vehicle (EV) driving range [1]. The limited EV range may be circumvented by having a DC fast charging infrastructure in place, capable of charging vehicles with a rate similar to refueling an internal combustion engine (ICE) vehicle. This infrastructure would allow in-city vehicle charging for apartment dwellers (i.e., without the possibility of home charging) and extend vehicle range during long trips, solving the EV range issue for most of the population. Building such an infrastructure has yet proven to be a major challenge, mainly due to available technology, competing industry standards and the impact on the grid [2,3]. Nevertheless, according to the most recent forecasts, the electric mobility market is starting to rise exponentially [4,5]. In particular, thousands of fast-charging stations are being installed all around the world at an incredible pace, as illustrated in Figure 1.
As a result of volume, weight and cost constraints, EV on-board chargers can reach limited power ratings (i.e., in the order of 3-20 kW) [6][7][8][9], which may be considered acceptable only for overnight charging. For every other use-case, high-power off-board DC chargers are required, achieving charging times comparable to refueling a gasoline car [3,10]. These chargers directly deliver DC current to the vehicle battery pack, meanwhile ensuring galvanic isolation from the mains. As of today, most commercially available DC fast chargers are rated between 50 kW and 150 kW [11], nevertheless a new generation of ultra-fast chargers (UFCs) rated at 350 kW and above are starting to be deployed [12]. # (thousands) Figure 1. Cumulative electric vehicle fast chargers installed worldwide, including AC 43 kW chargers, DC chargers, Tesla Superchargers and high-power inductive chargers [5].
Conventional DC fast charging stations represent a high-power, unpredictable and discontinuous load for the electrical system. The large scale diffusion of this kind of station is increasing the utility daily peak load, directly causing transformer overload and accelerated aging, meanwhile increasing system power losses [2]. Moreover, their total lack of flexibility leads to high peak power charges for the station operator, which are then reflected on the charging cost for the final users, and poses serious challenges to the power distribution system, affecting its stability and decreasing the power quality [13].
Most of the issues mentioned above can be addressed by having local energy storage at disposal, either leveraging the EV batteries (i.e., known as vehicle-to-grid operation) or installing separate storage to the station [14]. A correct sizing of the storage unit provides great flexibility to the charging station, allowing to reduce its peak power demand and the size of the protection equipment, thus leading to both lower operational costs and initial investment [15]. Moreover, the availability of stored energy opens up the possibility of providing grid ancillary services, such as (1) active power injection/absorption for grid frequency regulation, (2) reactive power support for voltage regulation, (3) grid harmonic reduction and (4) fault current generation during voltage dips/swells. These features can directly support the power distribution system, effectively turning around the drawbacks of conventional UFC stations, meanwhile allowing for an additional revenue stream for the station operator [16].
The reason behind the provision of such ancillary services lies in the design and structure of contemporary electric power systems find their roots in a more than a century old paradigm [17]. This paradigm relied on the centralized power generation from programmable sources (e.g., coal power plants), through synchronous generators (SGs), using the transmission lines and distribution networks to deliver the energy in a unidirectional way to the AC loads (i.e., motors, lamps, heaters, etc.). Therefore, the operation of such power systems was designed around the SGs, leading to quality indicators that reflected their correct behavior. These indicators are [17]: • a constant frequency (e.g., 50 Hz or 60 Hz); • a constant voltage amplitude; • a sinusoidal voltage supply with low harmonic content and limited harmonic interactions; • protection of the system in case of faults.
The SGs were, and still are, able to support and preserve these indicators, by providing the so called ancillary services.
The first grid power quality aspect is the constancy of the frequency. As it is designed, the power system guarantees the equilibrium between the active power demand and its consumption by keeping the grid frequency close to its nominal setpoint. Moreover, it is also important to keep the grid frequency within the given specifications to ensure the correct rotational speed of electrical machines directly connected to the grid, which are still widespread in industrial applications. This aspect is graphically illustrated by the power balance of Figure 2. This balance is perturbed in case of generation or load variations, therefore leading to a frequency drop or rise. With the goal of ensuring the correct operation of the grid without blackouts, the power system is equipped with frequency relays, which monitor both the grid frequency and its derivative (or rate of change of frequency, RoCoF), disconnecting portions of the network in case of faults. In this view, it is important both to minimize these frequency variations (reduced amplitude) and to reduce the RoCoF, in order to ensure a correct operation of the protections, with no untimely trips.

Generation
Load 50/60 Hz + − Figure 2. Qualitative representation of the electrical system power balance and its effect on the grid frequency. The power injected by generators is controlled to keep the frequency at its rated value.
The second cornerstone of power systems is the constancy of the voltage level. The amplitude of the voltage must be kept within the standard prescriptions and its variation is strongly related to the reactive power (at least in mainly inductive networks). It is therefore necessary to manage the reactive power flow towards the grid and this is currently done by SGs and other static compensators (e.g., capacitor banks or reactors).
Moreover, the electric grid requires a sinusoidal voltage with low distortion in steadystate conditions. In fact, the presence of harmonic and interharmonic components in the supply voltage may lead to the following detrimental effects: • additional high frequency losses in electrical equipment (e.g., transformers, motors . . . ); • worse performance of electric motors and generators directly connected to the grid; • poorly damped resonances between different components connected to the same grid; • disturbances in electronic equipment; • unwanted intervention of protection devices (e.g., breakers).
Therefore, it is important to avoid injecting harmonics into the grid and to compensate any harmonic content as much as possible. Thanks to their electromechanical construction, SGs are able to generate a voltage with a very low total harmonic distortion (THD) and are, therefore, highly suited to this purpose. Moreover, they are able to inject harmonic current when supplied with distorted voltage, as their stator offers a low impedance path to frequency components other than the fundamental.
Finally, the structure of the power system must withstand and clear short circuits. This means that the transmission and distribution networks are protected by breakers (e.g., equipped with overcurrent relays) to isolate faulty branches of the network and clear the fault. Again, SGs are appropriate to trigger such protections. In fact, in case of voltage reductions at their terminals, as it happens when there is a short circuit in the network, they automatically inject a fault current. Depending on the electrical distance from the point of fault (i.e., depth of the voltage reduction at the machine terminals), they inject a larger or smaller peak current. For near faults, they can easily inject a short circuit current few times larger than their rated value (e.g., 4-5 pu) without incurring into thermal protections, thanks to their long thermal time constant. Therefore, they are able to remain connected to the grid, riding through the fault and supporting the grid itself in abnormal conditions. Historically, the synchronous alternators of large thermoelectric power plants have been providing all the mentioned services. Nowadays, due to the decarbonization requirements and the rise of power generated by renewable sources, such power plants are being phased out [18]. For this reason, both academic and industrial research have been focusing on how to provide ancillary grid services by means of static grid-connected converters [19]. In this frame, a particularly promising technology is the virtual synchronous machine (VSM), which consists of making a power converter behave like synchronous machines, therefore providing grid ancillary services in the same way [20][21][22][23]. The advantage of this technology is that the inverter can mimic one or more aspects of a real SG, therefore contributing to the correct operation of the electric grid. Even though this solution has been mainly proposed for generating units (such as solar fields), it can be also applied to UFCs in order to make them more grid friendly, by providing ancillary services exploiting the already available power hardware. The simplest solutions found in the technical literature [24,25] focus on both active and reactive power exchange to the grid. Therefore, additional reactive power control loop and voltage regulators are added to the standard control algorithms of UFCs. These solutions are capable of providing only static ancillary services, such as primary frequency regulation and voltage regulation, but they are not able to generate suitable current references to compensate the grid during transients (i.e., sudden frequency variations, voltage dips or harmonic distortion). Much better performance can be obtained if UFC controllers are equipped with VSM algorithms, which are, on the contrary, well suited to generate the necessary ancillary services control signals.
Therefore, some researchers have proposed the integration of various VSMs into the control of both small power chargers and UFCs. Some propose partial ancillary services [26] (i.e., only frequency support), while others propose full VSM technology, which is able to provide both active and reactive support [27,28].
While these solutions guarantee satisfactory performance, they fully put the VSM model in charge of generating the power references of the converter. This means that both the compensating signals (ancillary services) and the necessary charging power references must be processed by the VSM model. However, this is not strictly necessary and a plug-in solution, where the VSM model is only in charge of the ancillary services, while keeping the standard structure of the UFC control, is preferable. Therefore, in order to fully exploit the potential of the next-generation EV UFC stations integrating energy storage, this paper proposes a Virtual Synchronous Compensator (VSC)-based control solution for the gridside bidirectional active front-end (AFE) converter. By leveraging the extended knowledge available on synchronous compensators, grid ancillary services may be provided in a straightforward and power system friendly manner, turning around the negative impact of standard unidirectional fast charging stations. Furthermore, since worldwide grid operators are moving towards the remuneration of some ancillary services [16] provided by large loads, the proposed solution would represent an additional source of revenue for the charging station operator.
The proposed compensator solution features the following benefits with respect to the existing literature: • the VSC algorithm is a plug-in addon for standard UFCs, enabling them to support the grid; • with respect to the early grid supporting UFCs, the VSC-based control is capable of providing both static (permanent) and dynamic (transient during faults) grid support; • the already available VSM-based AFEs are either partial (frequency control only) or put the VSM in charge of the complete management of the UFC, therefore not being an easy plug-in solution.
This paper is organized as follows. Section 2 describes the evolution of the fast charging station from the contemporary unidirectional paradigm towards more advanced bidirectional solutions. In Section 3, the global control scheme of the AFE converter equipped with the VSC technology is presented, along with some insights regarding the operation of the adopted VSC (the S-VSC, available in the technical literature). In Section 4, the proposed control strategy is validated experimentally and the main results are compared with a more traditional solution. Finally, Section 5 summarizes and concludes this work.

Ultra-Fast Charging Stations
State-of-the-art DC fast chargers are normally connected to the low-voltage grid, leveraging the low-voltage (LV) industrial power electronics expertise and availability. The structure of an off-board battery charger has no major differences with respect to an on-board EV charger and normally consists of two power conversion stages [3,6,7,10,11], schematically illustrated in Figure 3. The first stage is a three-phase grid-connected AC/DC converter with unity power factor correction (PFC) capabilities, also referred to as active front-end (AFE). The role of this stage is to absorb the correct amount of power from the grid while ensuring an input sinusoidal current shaping (i.e., with low distortion and harmonics) [29]. The second stage is a high-frequency DC/DC converter, which must provide the output DC current control (i.e., the regulation of the battery charging process) and galvanic isolation from the grid [30]. In general, both converter stages can be designed to be either unidirectional or bidirectional. A schematical overview of a conventional unidirectional DC fast charging station is provided in Figure 4. For reasons of simplicity and cost reduction, multiple identical off-board chargers are connected to the same point of common coupling (PCC). In this configuration, the power absorbed from the grid is equal to the sum of the charging powers, preventing any kind of operational flexibility. This results in a high peak power rating of the grid connection and safety equipment, leading to higher investment costs, and it impairs the possibility of flattening the load curve by distributing it within the day (i.e., when cheaper rates are available), thus also resulting in higher operational costs.  Having energy storage at disposal, either leveraging the EV batteries or adding separate storage to the station would allow to tackle the issues mentioned above. While exchanging power between the vehicle and grid may make sense for low-power chargers (i.e., with charging sessions of several hours), it is in contrast with the aim of high-power chargers. Therefore, at least the DC/DC converter stage should be kept unidirectional, limiting hardware requirements and simplifying communication and interconnection issues with the vehicles [3,31]. This consideration leads to the UFC station structure illustrated in Figure 5, where a single bidirectional AFE unit is designed for the whole station, generating a distributed DC-bus to which the isolated DC/DC stages (i.e., the actual EV chargers in this case) are connected. The energy storage is also connected to the bus by means of a DC/DC converter that regulates the power flow provided/absorbed by the storage unit. This enables the active power decoupling between the vehicle chargers and the grid, thus allowing for load shifting within the day. Therefore, the correct sizing of the storage unit allows to drastically reduce the peak power demand of the station and the sizing of the protection equipment, leading to both lower operational costs and initial investment [15]. Moreover, the bidirectional nature of the AFE, combined with the presence of energy storage, opens up the possibility of providing grid ancillary services such as frequency regulation, reactive power support, voltage harmonic reduction and short-circuit current generation during grid faults.

Active Front-End Control
Since the proposed control strategy does not depend on the AFE converter topology, in this paper a simple two-level inverter is considered. As shown in Figure 6, this inverter is supplied by a DC-bus connected to the energy storage system of the charging station. On the AC side, the inverter is connected to the LV grid through an LCL filter, which filters out the switching harmonics [32,33].
The control structure, also reported in Figure 6, consists of two cascaded layers, namely an outer S-VSC model and an inner current control loop. The measured quantities are the inverter phase currents i abc , the phase voltages across the filter capacitors v g,abc and the DC-link voltage v dc . This adds no additional cost compared to traditional AFE converters, since all these measurements are in any case necessary. Differently from a standard AFE, however, the proposed solution does not simply feature a v dc controller that provides the references for the inner loop. Instead, the current reference i * dq is obtained by adding up two separate contributions, namely the S-VSC power references P v , Q v and the external power references P * , Q * . The external power references P * and Q * , e.g., coming from the charging/discharging logic of the local storage or determined by the grid ancillary service agreements between the grid operator and the station owner, are directly fed to the inverter current control loop, while the S-VSC adds the extra power reference terms P v and Q v to compensate for grid perturbations. In particular, the reactive power Q is responsible for the voltage regulation at the AC side, while the active power P regulates the grid frequency and supports the charging process of the EVs and the local storage.  The most significant advantage of the proposed solution is the possibility to directly turn on and off the power reference signals coming from the S-VSC. Compared to other solutions, where the VSM model fully controls the power exchange with the grid, this control strategy allows to disable one or both power channels when they are not needed or when they are not part of the charging station operating plan. For instance, if the local storage must be recharged, the AFE contribution to transient frequency support might be limited or even excluded. The proposed VSC solution, therefore, fully acts as a plug-in control, able to enhance the grid-side performance of UFC stations with limited modifications of the standard control algorithms. In this paper, the inverter current control loops are implemented in a rotating (d, q) frame, which is aligned to the S-VSC rotor frame. The controlled currents are the inverter-side currents i abc , referred to the (d, q) frame as i d , i q . The grid phase voltages v g,abc are also referred to the (d, q) frame as v g,d , v g,q . The current reference vector i * dq is calculated from the total power references P = P * + P v , Q = Q * + Q v and the measured grid voltages v g,d , v g,q , as: The amplitude of the reference current vector is limited to comply with the inverter rating even during faults, without modifying its position in the (d, q) plane. Therefore, the ratio between the active and reactive component of the current is not altered. The current control (current controller block in Figure 6) can be performed using any of the existing strategies [34]. In this case, a PI + RES (tuned to the 6th harmonic) controller in the (d, q) rotating frame has been implemented. The tuning of the controller is performed according to previous literature, to obtain the optimal performance in both steady-state and transient operations [35].

S-VSC Model
To describe the S-VSC structure, it is practical to introduce a simplified diagram of the converter and control assembly. This diagram assumes that the inverter behaves as an ideal current source, injecting exactly its reference values into the grid. The system is therefore represented in Figure 7. The hardware part is modeled by a controlled current source i * connected to the grid through a CL filter. The current source reference is generated from the external power setpoints P * , Q * and the S-VSC virtual powers P v , Q v . The S-VSC is therefore a voltage-input, power-output model, where the input voltage v g is measured across the LCL filter capacitor C f . The current reference i * dq for the inner controller is derived from the sum of the external power setpoints P * , Q * and the S-VSC compensating power references P v , Q v , according to (1) and is then limited within ±I max to comply with the converter rating.
Control A novelty of the S-VSC is that it always operates with zero power references (i.e., P * v = Q * v = 0). The active and reactive power setpoints are processed directly by the inverter control loops and the virtual machine is only in charge of generating compensation references to provide grid ancillary services (virtual inertia, reactive support, harmonic compensation). The advantage can be explained with the load angle characteristic (P v , δ) of a synchronous generator, depicted in Figure 8. The stable operating region of a synchronous machine corresponds to the load angle interval [−π/2, π/2]. The VSG models available in literature operate over this whole stable region, radically changing their load angle according to the required active power flow. On the other hand, the S-VSC always operates around the point δ = 0, at nearly-zero active power (i.e., P * v = 0, P v ≈ 0). Therefore, when the active power transfer with the grid must change, only the converter control loops vary their operating point. The S-VSC does not change its load angle and it operates in parallel (i.e., independently) to the converter, similarly to a synchronous condenser, just injecting fractions of its nominal active power during grid transients. Moreover, in the S-VSC also the virtual speed ω r does not change significantly, as the virtual rotor does not have to modify its position with respect to the grid voltage vector. This leads to a better quality of the grid frequency estimation when using the S-VSC virtual speed, even during load transients. Moreover, this ensures both improved small signal and large signal stability, as a larger angle margin is available during grid faults [17]. The S-VSC is organized in several blocks, each in charge of a specific aspect of the VSM, as illustrated in Figure 7: 1.

Stable Operating Region
Power Calculation: calculation of the active and reactive power of the S-VSC from its virtual phase currents and the grid voltages.

2.
Mechanical Emulation: this is the virtual rotor of the machine. This block provides the virtual speed ω r and angle θ r of the VSM and frequency support to the grid.

3.
Excitation Control: reactive channel management, virtual excitation flux control for reactive support during faults and short circuit current injection.

4.
Electrical and Magnetic Model: virtual stator and optional virtual dampers. Provides tunable harmonic compensation.

Power Calculation
This block calculates the feedback virtual active power P v and virtual reactive power Q v for the S-VSC model. These virtual powers are calculated from the virtual machine current i v and not from the actual inverter current i. This guarantees higher immunity against the measurement uncertainties and avoids the introduction of non-linear effects due to the current saturation in case of inverter overload.
The virtual active and reactive powers of the S-VSC are calculated from the measured grid voltage and the S-VSC virtual currents as: The virtual powers are assumed to be tracked by the converter control with zero error. This assumption is valid since the response of this controller is much faster than the power variation dynamics of the S-VSC (i.e., less than ms vs. hundreds of ms to s).

Mechanical Emulation
This is the key part of the S-VSC. In fact, it is in charge of the grid synchronization of the converter controller, providing a measurement of both the grid frequency ω g and angle by the virtual rotor speed ω r and angle θ r . In the S-VSC model, a simplified version of the synchronous generators swing equation is implemented. The well-known swing equation [17] is here simplified by removing the damping term D p (ω r − ω g ), proportional to the speed error between the virtual rotor and the grid. The electrical feedback power P e is here the virtual machine power P v and the prime mover mechanical power P m becomes the virtual reference active power P * v . The inertia constant H of the machine here becomes the virtual inertia constant of the machine, but it still preserves the same meaning. The result is depicted in the block diagram of Figure 9a.

Excitation Control
Another core block of the S-VSC is represented by the excitation control [36]. This block deals with the reactive power management of the virtual machine. In summary, the excitation control acts as a reactive power Q v integral controller, generating the virtual excitation flux linkage λ e for the VSM electrical part. This block is crucial during voltage dips and short circuits, since its action provides the necessary excitation flux to inject or absorb reactive power to support the voltage and/or trigger the short circuit relays. As shown in Figure 9b, the implemented excitation control is of integral type, according to defined by its gain k e and time constant τ e . As already mentioned, the reactive power references of the S-VSC are set to zero (Q * v = 0), being the external active and reactive power setpoints directly fed to the converter. Therefore, in steady-state, the reactive controller regulates the virtual reactive power of the S-VSC to 0.

Electrical and Magnetic Model
The electrical equations of the S-VSC emulate a virtual stator in the (d, q) rotating frame and a simplified damper winding on the q-axis [37]. As for real electrical machines, the excitation flux acts on the d-axis (reactive axis), while the q-axis deals with the active power (torque). This is a slight difference compared to traditional PLL-oriented grid-tied converters, which relate the d-axis with the active power (in phase with the grid voltage) and the q-axis with the reactive power (in quadrature). The equivalent circuits of the S-VSC electrical part are depicted in Figure 10. Such equivalent circuits are similar to the ones found in the traditional modeling of synchronous alternators [17].
Compared to synchronous alternators, the non idealities (e.g., saturation) and other unnecessary features for the synchronous machine emulation (e.g., damper windings on both axes, dynamics of the excitation winding) are excluded. It can be observed that the d-axis circuit comprises the excitation flux linkage λ e . The resulting per unit electrical equations of the virtual machine are: where R s is the stator virtual resistance, λ d and λ q are the virtual stator flux linkages and ω b is the base angular speed. The other parameters of the equivalent circuits are the virtual inductance L s and the virtual damper inductive and resistive parameters L rq and R rq . The virtual currents i d and i q of the S-VSC can be calculated through the inverse magnetic model of the machine as follows [37]: Figure 10. S-VSC d-axis (a) and q-axis (b) equivalent circuits.
As a further note, the S-VSC virtual stator also naturally embeds a harmonic compensation feature. Just as real synchronous machines, also the S-VSC is able to generate compensating current references to counteract harmonic distortions of the grid voltage. The virtual stator acts in steady-state as a virtual inductance L s , since the resistance R s is usually much lower and is therefore neglected. Therefore, this virtual stator circuit, when supplied by a grid voltage including n arbitrary harmonics of order h, generates the following harmonic current references: where i h αβ and v h αβ are reported in the stationary (α, β) frame. This means that the S-VSC is able to generate a compensating current, that is inversely proportional to the virtual stator inductance L s . Therefore, since the virtual stator inductance is tunable, the magnitude of the injected current can be varied. It must be noted that a suitable current controller is needed to track high order current harmonic references.

Experimental Validation
The proposed VSM-based control of the UFC station AFE has been implemented on a 15 kVA grid-connected inverter to validate it experimentally. Figure 11 shows a picture of the experimental setup. The DC source output voltage, representing the local storage of the charging stations, is set to 400 V. The 50 kVA grid emulator provides a 220 V RMS line-to-line grid voltage at 50 Hz. The controller (VSM + current control) is implemented in C-code on a dSPACE 1005 controller. The control is executed at f s = 10 kHz, which corresponds to the switching frequency f sw . The grid interface LCL filter parameters as well as the S-VSC parameters are listed in Table 1.  These tests demonstrate that the proposed control solution can provide the necessary ancillary services to the grid. In particular, (1) it can support the grid frequency during load unbalances, (2) it can contribute to the static voltage regulation by injecting reactive power, (3) it provides a low impedance path for current harmonics, mitigating the grid voltage distortion at the PCC and (4) it can provide dynamic reactive grid support by injecting reactive fault current in case of voltage dips.
Finally, a comparison between the proposed solution and a Distribution Static Synchronous Compensator (D-STATCOM) is also provided to demonstrate the superiority of the proposed design.

Test 1: Inertial Action
The first test aims to prove the active support capabilities of the proposed solution. This is done by emulating with the grid emulator a large load unbalance, representing the loss of a large power generating unit. In the tested case, the grid frequency drops to the frequency nadir of 48.7 Hz and then settles to the post fault value of 49.6 Hz. The frequency variation is chosen to be larger than standard occurrences in order to magnify the effect of the proposed solution. As it emerges from Figure 12a, the proposed solution effectively injects active power proportionally to the inverse of the grid frequency derivative. The active power injection stops as soon as the grid frequency settles to its final value of 49.6 Hz. During the transient, the S-VSC does not lose synchronism with the grid and manages to track its frequency in an accurate way.
A supplementary test is performed, applying the same frequency perturbation from the grid emulator. In this case, a proportional frequency control (droop coefficient b = 5%) is added externally, generating an active power reference equal to where the setpoint ω * is set to the rated European frequency of 50 Hz. As shown in Figure 12b, the S-VSC still contributes with inertial active power P v exactly as in the previous test. However, the total active power injected by the inverter P is now the sum of P v and the droop contribution P d . This latter power term provides a static frequency regulation and contributes to restoring it to the rated value. It must be noted that the participation to primary frequency control (active droop) is usually an optional feature and in the case of UFCs it could represent an additional stream of revenues after proper agreements with the grid operator.

Test 2: Reactive Power Generation
The proposed AFE control structure can also take part to the voltage regulation, by injecting or absorbing reactive power. The static voltage regulation law has to be implemented according to the grid standards (e.g., [38]) and generates a reactive power reference Q * . The proposed control structure is able to track this reference as shown in Figure 13. In this case, the reactive power reference Q * is changed from 0.3 pu to 0.4 pu. The overall dynamic response depends on the tuning of the current controller and optional filters, not being directly processed by the S-VSC.

Test 3: Harmonic Compensation
To prove the harmonic compensation capabilities, a distorted grid is generated by means of the grid emulator. A 5 % 5-th harmonic voltage distortion is introduced. The effect of the VSC is beneficial, as results from the DFT analysis presented in Figure 14. In particular, the 5-th voltage harmonic is attenuated from 6 V to 4 V, proving the effectiveness of the harmonic compensation feature.

Test 4: Fault Current Injection
The behavior in case of short circuits in the grid is tested by applying a voltage dip from the grid emulator. The voltage dips are chosen according to statistical data available in the technical standards [39]: • Dip 1: −20 % and 300 ms duration; • Dip 2: −20 % and 60 ms duration. These can be representative of a fault in the medium-and high-voltage grid, respectively. As it is shown in Figure 15, the AFE injects short circuit reactive current during the fault for grid support and triggering of protection relays. Moreover, the reference current is clamped to the limit value I max (set to 36 A in such tests), meaning that the reactive power is limited to 0.5 pu. This limitation is even clearer when looking at the amplitude of the injected current, which is strongly limited to the design value of 36 A. The duration of the current injection can be tuned by modifying the time constant τ e of the excitation control. The beneficial effect of the fault current injection is already visible in this test. As mentioned, the voltage dip depth is 20 % in both dips. A starting voltage of 92% was applied; therefore, the residual voltage would be equal to 72 % (with no reactive power injection). However, the S-VSC reactive injection supports the voltage at the PCC and increases it up to around 77% in both cases (see Figure 15), therefore proving the successful grid supporting capabilities of a UFC equipped with the S-VSC.

Performance Comparison with D-STATCOM
In distribution systems, D-STATCOMs are employed to actuate static voltage regulation [40,41]. Moreover, they can provide other ancillary services such as inertial support [42] and harmonic compensation [43]. Therefore, the previous tests are repeated replacing the AFE with a D-STATCOM in order to compare the behavior of the two solutions. These tests are performed by means of simulations in PLECS environment.

Inertial Action
The hardware of conventional D-STATCOMs only features a capacitive DC-link, with no energy storage, thus representing a strong limitation to the frequency support capabilities. Therefore, traditional D-STATCOMs are not suitable to actuate frequency regulation, neither inertial nor permanent, as demonstrated by the result of Test 1 (see Figure 16). Nevertheless, STATCOMs can be used to provide limited frequency regulation, by adding suitable inertial controllers and allowing for the charging/discharging of the DClink capacitors. In particular, they can only operate in the first few ms of a load unbalance, after which the DC-link capacitor voltage reaches critical levels and the inertial active power can no longer be injected into the grid [42]. On the other hand, the solution proposed herein is a VSC integrated into an ultra-fast charging station with local storage. As a consequence, the frequency support is not limited to a short inertial action and is decoupled from the DClink capacitors, thanks to the energy storage system installed in the station. As previously shown in Figure 12, the proposed S-VSC is both able to provide inertial support and long-term frequency regulation, as opposed to the limited inertial action (i.e., at most) of a STATCOM.

Reactive Power Generation and Fault Current Injection
In general, traditional STATCOM reactive controllers can be divided in two categories, which employ different control strategies: • Reactive Power Control: the STATCOM tracks an external reactive power reference, coming, e.g., from the grid operator. Figure 17 shows the response of the D-STATCOM for Test 2, where a reactive power step from 0.3 pu to 0.4 pu occurs. In this case, no differences are identified between the D-STATCOM and the proposed S-VSC solution.
• AC Voltage Amplitude Control: a proportional integral (PI) voltage amplitude control is implemented, generating the necessary reactive power references. This controller is able to support the grid voltage during faults, by injecting reactive current. However, in case of a permanent voltage dip, the injected current remains constant, as shown in Figure 18. On the contrary, the results reported in Figure 19 demonstrate how the S-VSC injects reactive fault current in the same way as a synchronous machine (i.e., exponential transient of the fault current). Therefore, D-STATCOMs are suitable for static reactive support, but they require more advanced controllers to emulate the behavior of synchronous machines (e.g., fault current shape). In fact, during voltage dips, the reactive short circuit current injected by the D-STATCOM quickly grows and saturates and this solution cannot adapt to modified grid voltage conditions, differently from the S-VSC. Nevertheless, from a hardware perspective, a STATCOM could provide the same reactive performance of the proposed S-VSC solution; however, it would require a modified control strategy.

Harmonic Compensation
Traditional STATCOM controllers cannot provide harmonic compensation, as opposed to the S-VSC solution. During Test 4, a 5 % 5-th harmonic distortion is added to the ideal grid voltage. As shown in Figure 20, the D-STATCOM does not react, leaving unaltered the distortion at the PCC. With the implementation of additional controllers, STATCOMs can provide harmonic compensation [43], however affecting the controller complexity.

Overview
It can be concluded that the proposed S-VSC control strategy applied to the AFE of a bidirectional UFC station outperforms traditional D-STATCOMs, being able to condense in a single controller all of the relevant grid ancillary services. The main advantage of the proposed S-VSC solution resides in the integration of the S-VSC control into the existing hardware of the charging station, therefore exploiting in a better way the power hardware that is anyway installed. STATCOMs, on the other hand, are specific equipment for grid support and require a dedicated and expensive installation, being only exploited for compensation purposes.

Conclusions
This paper has proposed a VSC-based control of the grid-connected front-end of an EV UFC station with integrated energy storage. The proposed control solution strongly improves the behavior of the charging station from the utility point of view, providing the following grid ancillary services: • frequency support with inertial action; • reactive power generation for grid voltage support; • harmonic compensation; • fault current injection in case of grid-side faults to trigger the utility protections.
The provision of such services can be both beneficial from a technical stand-point (i.e., supporting the stability of the grid) and from an economical point of view, if new regulations are implemented. With such new regulations, the contribution of EV charging stations to grid ancillary services could be remunerated, and consequently generate an additional profit stream for the station operators.
The proposed S-VSC control strategy has been validated experimentally and has been shown to outperform traditional D-STATCOMs. The proposed charging station concept can effectively support the grid when needed, therefore representing a viable solution for a simpler integration of UFCs into the power distribution grid.