Tackling the challenges of the energy transition requires a skilled workforce and advanced educational and training tools. During the previous years, a relatively large number of institutions have acquired Real-Time Simulators, in both academia and industry. However, this is mainly used for practical studies and research, while the use of real-time Hardware-In-the-Loop (HIL) simulation for education and training is rather limited at the moment. In this framework, this work investigates the potential of using HIL simulation for education and training purposes on power and energy topics in both academia and industry. Selected reference experiences of the Task Force members are presented along with learners' feedback to substantiate the effectiveness of the approaches. Particular attention is given to training and education at industrial level, which has not been adequately addressed in the literature, so far. The use of remote laboratories and safety concerns are also addressed.

This study uses an efficient variance-based sensitivity analysis method to examine the influence of control parameters on the behavior of DC fault currents in an MMC-MVDC system. The interaction between control and protection dynamics during DC faults influences the converter's contribution to the DC fault. Understanding the impact of control parameters on the converter's fault response and revealing critical parameters is helpful for effective protection devices and system design.

The hybrid synchronization control (HSC) method and active susceptance controller (ASC) have been demonstrated to be effective approaches for addressing the instability of grid-forming inverters under strong grid conditions. In this paper, HSC and ASC are demonstrated to share the same essence—introducing a voltage-based synchronization loop. Furthermore, differing from previous studies that rely on small-signal analysis, this paper establishes a unified large-signal model for both HSC and ASC to characterize the inertia and damping, and to elaborate that how they affect the dynamic responses. Based on the large-signal model, it is revealed that the introduced voltage-based synchronization loop of both HSC and ASC reduces the damping and inertia, thereby resulting in a faster response and higher overshoot. The findings are confirmed by the experimental results.

Interoperability in HVDC systems could be supported with open upper-level control and protection (C&P) software, while hardware-near C&P functions stay black-boxed and proprietary. Methodologies like model-based systems engineering and graph theory can assist in defining the boundary between open and closed software. Most likely, partially open C&P software in HVDC is not hindered by legislation, but has to be addressed in contractual agreements. Also, a new responsibility matrix for testing is proposed.

The growing deployment of high-voltage direct current (HVDC) systems requires addressing the complexities of multi-vendor integration. This paper explores the evolving role of the HVDC integrator, which brings together components and systems from various vendors, ensuring compatibility and system performance. The paper reviews and compares existing literature on potential models for HVDC integration, particularly contrasting transmission system operator-led versus consortium-led approaches. Using input from different industry stakeholders, the paper further investigates different implementation models, ranging from joint ventures to publicly and privately owned competence centers. The discussion also covers the critical role of information sharing, software openness, and intellectual property protection in facilitating multi-vendor interoperability. In conclusion, while current business and regulatory frameworks present challenges, the paper envisions a long-term goal of a certifier integrator model, which could streamline the integration process as HVDC systems mature and become more standardized.

The growing deployment of high-voltage direct current (HVDC) systems requires addressing the complexities of multi-vendor integration. This paper explores the evolving role of the HVDC integrator, which brings together components and systems from various vendors, ensuring compatibility and system performance. The paper reviews and compares existing literature on potential models for HVDC integration, particularly contrasting transmission system operator-led versus consortium-led approaches. Using input from different industry stakeholders, the paper further investigates different implementation models, ranging from joint ventures to publicly and privately owned competence centers. The discussion also covers the critical role of information sharing, software openness, and intellectual property protection in facilitating multi-vendor interoperability. In conclusion, while current business and regulatory frameworks present challenges, the paper envisions a long-term goal of a certifier integrator model, which could streamline the integration process as HVDC systems mature and become more standardized.

A method is presented to assist in the design of control and protection parameters for a Medium Voltage Direct Current (MVDC) system using a Single-Layer Perceptron (SLP) type of Neural Network. Unlike studies that typically verify control and protection parameters separately, in this work different operational scenarios are considered to analyze the joint performance of control and protection design. Then, a neural network is trained to learn the correlation between these parameters and the outcomes of success or failure cases. Tests are conducted using a modular multi-level converter (MMC) topology in an MMC-MVDC point-to-point system. The MMC-HVDC system is modelled in MATLAB/Simulink, and the SLP is developed using the Keras library (integrated with TensorFlow) in Python.

The increasing dominance of inverter-based resources (IBRs) in power generation leads to significantly faster frequency dynamics in modern power systems. Therefore, the secondary control within the classical hierarchical structure must operate significantly faster. However, high communication burdens are inherent to centralized implementations of secondary control. This paper proposes a faster, distributed model predictive control (MPC) scheme for secondary frequency control of inverter-based power systems. The controller predicts the IBRs' local frequency dynamics by considering the impact of the primary control of nearby IBRs. To obtain an optimal model-predictive control problem consisting of distributable subproblems, we introduce a novel trimming procedure to the frequency divider concept, an analytical formulation that estimates the local frequency at system buses. These subproblems have a tunable degree of mutual coupling. The presented distributed MPC achieves fast, error-free frequency regulation in the presence of abrupt load changes while also being robust to communication losses of participating IBRs. By design, the distributed control relies on a sparse neighbor-to-neighbor communication structure and uses local MPC problems that do not scale in complexity with system size. Numerical simulations of the IEEE 39-bus system and an extended CIGRE medium voltage power system demonstrate the fast performance of the proposed distributed MPC scheme for secondary frequency control.

This paper presents a novel Nested Identical Control (NIC) method for load frequency control of multi-area microgrid systems employing two novel variants of the Chameleon Swarm Algorithm (CSA). Load frequency control, a common strategy to counter power system instabilities from load fluctuations, poses a significant challenge. Maintaining system stability amidst substantial load shifts becomes particularly challenging in complex power networks spanning multiple areas with several generators. To address this, we first designed two novel variants of CSA called Quasi-oppositional CSA (QCSA) and Quasi-Levy-oppositional CSA (QLCSA). In QCSA, a quasi-oppositional-based learning operator is used to improve the diversification and intensification of CSA. The QLCSA incorporates the Levy flight operator into the QCSA to avoid stagnation and local minimal entrapment. We evaluated the efficiency of these variants against the original CSA and five other highly performing algorithms on the IEEE Congress on Evolutionary Computation benchmark functions. Subsequently, we employed the new CSA variants to design a NIC for load frequency control of a two-area microgrid system, considering different cases of uncertainties. The NIC strategy is designed such that the controller parameters of each loop in one area are inherited by the controller of the corresponding loop in the second area, with a target to achieve <3% overshoot in every frequency fluctuation and < 10 sec of settling time. Simulated results on the benchmark functions prove the superiority of QLCSA and QCSA over CSA and the selected highly-performing algorithms. The dynamic responses of the NIC-controlled microgrid system in numerical time-domain simulations show the effectiveness of the proposed control approaches when compared with PID control tuned using MATLAB's control system tuner.

Interoperable multi-vendor High-Voltage Direct-Current (HVDC) grids are a key enabler for the integration of renewable energy (in particular offshore wind) and its transmission over longer distances to consumers. However, most HVDC systems today are single-vendor and point-to-point. Various technical and non-technical aspects need to be considered, for example, (real-time) testing, legal aspects (intellectual property and regulation), and the multi-vendor interoperability process. This paper presents findings from the READY4DC project, which is a larger and open European effort involving diverse stakeholders, including HVDC manufacturers, transmission system operators, wind developers, academia, and research institutes. It summarizes key technical recommendations, emphasizing comprehensive interaction studies and the development of a structured legal framework to facilitate the development and operation of a multi-vendor, multi-terminal HVDC grid. The READY4DC project highlights the need for increased harmonization, transparent communication among stakeholders, and future-oriented research to ensure the robustness and interoperability of interconnected grids. Collaborative efforts are key for addressing technical complexities and advancing the deployment of multi-vendor multi-terminal HVDC technology.