In order to perform demand side management (DMS) in NEDO project network analysis and consumer data has been studied for the substation Breg. Load flow analysis and critical network operating states were carried out on the basis of DSO Network Development study for the Region of Ptuj. Load time series data analysis consists of four parts: substation analysis, feeders analysis, low voltage consumers analyses and load-temperature correlation. The active power time series data from transformers' measurements in a substation for the past 4 years (2013 to 2016) was examined. The DG active power time series data was also acquired and analysed. In demand response program only consumers below 43 kW can be controlled and there is also 50 hours of demand response activation available per year. With 50 hours of demand response activation available per year the yearly substation peaks can be decreased for around 1 MW [5 % P_yearly_max].

Within the framework of the NEDO-DR project, we focus on short-term reduction in peak power consumption for the needs of the electricity network. One of the tools used to reduce end-consumer consumption is to adjust tariffs to power network conditions.

The report represents the evaluation of the demand response activations using various statistical and machine learning methods. First, we represent the activation statistics for Critical Peak Tariff (CPT) and System Balancing (SB) activations which lasted from January 2018 until November 2018. The proposed methodology for assessing the baseline load uses probabilistic load forecasting techniques in order to improve the evaluation of the demand decrease throughout the program. Results are represented with various statistical diagrams.

Transmission System Operators are responsible far the security of operations, facilitation of regional markets and integration of RES. Thus, the development of grid infrastructure, supporting technologies and market mechanisms are key elements far a proper and timely integration of renewables. In addition, TSOs also address network ageing issues and weather related risks with technical solutions which keep the electric system secure at acceptable costs. In recent years, the Slovenian and Croatian electricity systems have been increasingly challenged by faur contradictory influences impacting the operations of both electricity systems: l. A constant support ofRES integration to meet the EU ambitions 2. A lower electricity consumption due to the economic crisis, 3. A growing Jack of centralized electricity generation able to provide ancillary services, 4. The high interconnectivity between the neighboring control zones. Consequently, the Slovenian and Croatian TSOs, together with DSOs, observe growing network overvoltage issues as well as a decrease in secondary reserve capacities. The security of supply is therefare at stake which, in turn, impact further national and regional RES integration targets. The Slovenian and Croatian TSOs and DSOs started separately addressing these issues in 2014. Classical engineering approaches were taken into account in the two existing TYNDPs. They studied first the implementation of technical measures within each control zone, but soon came to the conclusion that: uncoordinated actions, taken in one of the two control zones would significantly impact the other since these two control zones are highly interconnected; a progressive deployment of technological solutions would be less efficient since the same issues would resurface soon, leading to repeated investments in order to keep the security of operation above critical bottom line figures; in the long-run, uncoordinated approach would not lead to a satisfactory level of security of operation while allowing far hosting higher levels of RES integration and maintaining a sufficient level of ancillary services in both electricity systems. Therefore, joint actions would create synergies and address the very same issues in a more sustainable way. The TSOs and DSOs therefore agreed to work together to address all the pending issues and designed a joint cross-border systemic approach to bring lasting solutions to all of the four above issues at once. They end up with the SINCRO.GRID investment project: it is an innovative system integration of several mature technology components where synergies among all the proposed solutions are searched to maximize the investment impact onto both electric systems, while creating further regional benefits. SINCRO.GRID will deliver an increased security of operation to reach acceptable levels for at least the next ten years, this with no need for repeated investments to maintain this acceptable security level, while hosting levels of RES foreseen to reach the 2030 targets in an integrated and competitive market. The SINCRO.GRID project integrates new active elements in the transmission and distribution grids which are managed via a virtual cross-border control center involving advanced data management, common system optimization and generation/consumption forecasting, thanks to an increased cross-border cooperation between TSOs and DSOs. The project leans on five main pillars as described in the following table. The project's investment costs amount to 88.6 M EUR.