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While peer-to-peer energy trading has the potential to harness the capabilities of small-scale energy resources, a peer-matching process often overlooks power grid conditions, yielding increased losses, line congestion, and voltage problems. This imposes a great challenge on the distribution system operator (DSO), which can eventually limit peer-to-peer energy trading. To align the peer-matching process with the physical grid conditions, this paper proposes a cost causality-based network cost allocation method and the grid-aware peer-matching process. Building on the cost causality principle, the proposed model utilizes the network cost (voltage, congestion, and loss) as a signal to encourage peers to adjust their preferences ensuring that matches are more in line with grid conditions, leading to enhanced social welfare. Additionally, this paper presents mathematical proof showing the superiority of the causality-based cost allocation over existing methods. • Proposing a causality-based cost allocation method. • Demonstrating the superiority of causality-based cost allocation. • Designing coordination P2P energy trading and network operation using network costs allocation. [ABSTRACT FROM AUTHOR]

• Explores the changing roles of TSOs and DSOs in the active energy sector, highlighting the complexity of their changing responsibilities and the challenges faced by each operator. • Underlines the critical need to improve coordination between TSOs and DSOs, focusing on the integration of DERs into this complex framework, and examines the associated challenges and strategies developed to overcome them. • Outlines various TSO-DSO coordination models, discusses key stakeholders, highlights successful real-life projects implementing coordination strategies, and ultimately aims to provide the energy industry with a comprehensive roadmap for future developments. The digitalization transforms grids into a much more complex grid structure than it is today. Based on this transformation, commitments to renewable energy sources (RESs), energy integration at large and small scales, bidirectional energy flows, and storage resources are increasing. Because many of today's electrical grids are obsolete, these developments require radical changes to our existing power systems. The flexibility of the market is essential for the increasing number of small and large-scale producers, consumers, and prosumers. Transmission System Operators (TSOs) and Distribution System Operators (DSOs) will be key buyers from this market, but their effectiveness depends on efficient collaboration and use distributed flexibility resources at scale. In particular, Distributed Energy Resources (DERs) play an essential role in ensuring market flexibility and balancing flexible networks. The use of DERs at both the transmission and distribution level enables collaboration between TSOs and DSOs. This article discusses the individual roles of TSOs and DSOs and the challenges they face in the power system. Coordination schemes and key stakeholders are presented. It comprehensively examines optimization-based solution and blockchain-based applications developed for TSO and DSO coordination challenges and provides a roadmap for developing a more efficient, reliable, and sustainable power system in the future. [ABSTRACT FROM AUTHOR]

The purpose of this work is to provide an insight for a possible methodology to implement demand response strategies at a city scale. The objective is to determine a range of values for the energy and power that can be made available through the large deployment of a residential energy management system. This work can help the distribution system operator to assess the impact of the usage of such technology at the grid level. The paper describes a methodology that identifies the start of operation cycles of appliances and other loads on a given general load diagram, enabling the simulation of load shifting caused by the operation of residential energy management systems. A simulation of an hypothetical 20% deployment of a residential energy management system on the city of Coimbra in Portugal, was performed. The results show the release of almost 3% of the demand on periods of higher price, but also the occurrence of a pronounced peak during the night period, an occurrence which may need to be dealt with, and for which some solutions are proposed. [ABSTRACT FROM AUTHOR]

• Voltage data processing based fault detection and its isolation is proposed in multiple operating modes of Micro grid. • A fault locator module is designed using Gaussian process regression which can predict the exact fault location using simple measurements at source buses. • No complex signal processing is involved in designing the ML model which makes the FLM fast and efficient. Modern intelligent digital relays embedded with phasor measurement units have facilitated easy access and collection of electrical signals in a microgrid. In this paper, a model for detection, location and isolation of faults in AC microgrid is presented. The real time voltage, frequency and current data are processed via simple formulations to detect the fault. The tripping command is promptly communicated to the incumbent line relays within fault tolerance time, after fault detection. The proposed scheme assures reliable protection in grid connected and islanded mode of operation with added security in case of primary protection failure. Post tripping, the exact location of fault in any distribution line from utility grid is predicted using a fault locator module. This module is designed and developed by gaussian process regression technique. Further, various machine learning techniques used for fault location has been explored and compared to establish the superiority of GPR method over others. Also the features extracted for model training is quite simpler, which imposes less computational burden on central protection computer. An IEEE 15 bus distribution system with synchronous and solar photo voltaic based DG is simulated in EMTP-RV platform to generate the electrical data. Further the required calculations are performed in MATLAB 2020a [ABSTRACT FROM AUTHOR]

• The DSO participates in the balancing market as a balance responsible party. • DSO scheduled actions are reflected on TSO balancing market clearing results. • Flexibility resources provide flexibility at distribution and/or transmission level. • Pan-European market-based coordination at distribution and transmission level. • Aligned operation of flexibility markets at distribution and transmission level. This paper proposes a framework for DSO-TSO market-based coordination in a feasible and transparent way, compatible with the European-type electricity market. The DSO participates in the balancing market as a Balance Responsible Party, by submitting price-taking offers that represent the net outcome of DSO scheduled actions at the distribution level. With this approach, the balancing market clearing results reflect the impact of scheduled actions at distribution level on system power balance. In addition, specific design aspects of the DSO market are highlighted that could align DSO and TSO market, increasing the market coordination efficiency and promoting the wider participation of distributed energy resources in both markets. The advantages of the proposed method are: (a) more accurate balancing market pricing signals while congestion management services and balancing services remain decoupled, (b) low data exchange requirements between the two Operators, (c) distributed energy resources opportunity to participate efficiently either in one or both markets, and finally (d) easy pan-European market-based coordination of TSOs-DSOs based on current balancing market development action plans. [ABSTRACT FROM AUTHOR]

• Hydrogen based systems equipped with a storage can improve renewable integration. • Micro genetic algorithm results adequate to size hydrogen systems. • Decentralized control allows managing hydrogen systems in secondary substations. • The studied distribution system achieves 38.7% of self-consumed renewable energy. • Reverse power flows are reduced of 14.7% by means of 10 hydrogen systems. The increasing penetration of distributed generation at LV and MV level is a hard challenge for Distribution System Operators (DSOs). Hydrogen technologies have recorded a great interest in the last decades as promising drivers for the energy transition. This paper proposes the installation of Hydrogen Systems (HSs), consisting of Fuel Cells, Electrolysers and hydrogen storage, in order to increase energy performances of the Distribution Network (DN) and to better integrate distributed generation. HSs location and sizing problem is solved considering the necessity for DSOs to ensure the secure and stable DN operation. HSs are not influenced by other end uses related to other energy sectors and are characterized by a fully decentralized management system, applicable in Secondary Substations (SSs). The evaluation is based on the concept of Energy Districts (EDs), defined as a group of SSs that present a single point of connection with the rest of the radially operated DN. The DN of the city of Terni is the real case study: available data measured at SSs for every quarter hour of year 2019 are used. 10 HSs are installed by the algorithm, reaching a high rate of renewable energy self-consumed and a relevant decrease of Reverse Power Flows. [ABSTRACT FROM AUTHOR]

• Security-constrained model for clearing distribution market in microgrids presence. • Maximizing the social welfare of distribution system. • Contingency and microgrids' islanding capability in distribution market clearing. • Impact of microgrids' islanding on nodal prices. This paper proposes a security-constrained distribution system market clearing model in presence of proactive customers, and in particular, microgrids. This problem is solved by a distribution system operator (DSO) which acts as a market-driven distribution management entity. The system security consists of distribution line outage as well as microgrid islanding. None of these two security events are in the control of the DSO, so associated uncertainties are considered in the problem modeling. Moreover, the interdependency of the microgrid islanding to distribution line outages is taken into account. Numerical simulations on the IEEE 33-bus standard test system exhibit the significance and the effectiveness of the proposed model. [ABSTRACT FROM AUTHOR]