Accurate and reliable state estimation is the core stone for flexible operation and control of active smart grids. Through the current expansion of integrating DG units in low voltage networks, the network operation is becoming more complex than before. However, real-time monitoring and control through state estimation is a routine task for the transmission system operators (TSO's) due to the availability of measurement data. The distribution system operators (DSO's) are trying to extend their monitoring and control for medium and low voltage network in order to enable smart grid applications. With the current rollout of smart meters, which are considered as a key component of future smart grids, there would be enough metering data in the distribution networks (voltage, current, active and reactive power consumption and generation) available at every customer connection point. This paper aims to develop a method to solve the problem of meter placement for low voltage sy stem state estimation through deciding which measurement data from the installed smart meters should be considered in the state estimation algorithms in order to improve on the uncertainty of the estimated voltage and its phase angle at every node in the network
Accurate and reliable state estimation for low voltage networks is the corner stone for flexible operation and control in the current transaction from passive conventional grids to active smart grids. The development in the energy supply has revealed a rapid increase of controllable distributed generators, consumer installations, stationary storage systems, and electric vehicles. This development has led to a significantly different kind of system behavior which must firstly be understood, and then suggestions for operational network improvements in order to increase the security and efficiency of the distribution system operation can be made. Following this, a high chronological and topological resolution of information for the system state estimation in the low voltage level is necessary. However, measurement data are necessary for state estimation. These measurements can be obtained either from the distribution system measurement infrastructure or from the smart mete rs installed at the customer's connection points. The focus of this paper is to develop and validate a state estimator for low voltage networks with distributed generators and to obtain the technical feasibility of using smart meters and their measurements for low voltage network observability and controllability
For the deployment of future ICT-infrastructure within smart grids, a huge synergy potential between the telecommunication and the energy sector is expected. However, our analysis shows that there are substantial strategic hurdles to overcome in order to foster cooperation between communications providers and Distribution System Operators (DSOs) as there are various asymmetries among them. The main reason for cooperation among the energy and communications sector consists in assumed advantages, e.g. faster implementation of smart grid services and solutions. The regulatory framework, which is perceived to be in need of further clarification, has been identified as the main hurdle for cooperation , while technical issues are not as important. DSOs and communications providers showed substantially different opinions when it comes to their particular assessment of the cooperation potential between the two sectors. Additionally, this assessment also depends highly on the smart grid use case in question.
Driven by the increasing need to expand grid capacities due to the sustained integration of distributed renewable energy sources (especially photovoltaic generation in low voltage grids), solutions for an economic justifiable approach are needed. The majority of the provided options by the OEMs lead to an increased amount of data and control complexity in order to operate the additional equipment. To avoid dependencies on a higher control instance and to reduce the needed effort to operate a distribution grid covering a large area, local control strategies could provide a solution. In a small village, the EnBW electricity company runs a pilot project and tests different options for low voltage (LV)-grid load shedding. To implement and validate control structures under real conditions is an inherent part of the research program. This paper shows the general approaches chosen for the design of a control system as a local micro grid, as well as the first results from the phase of practical testing.
The development of automated production systems is subdivided in two mayor tasks. One is the development of the processes needed to meet the requirements for the product, the other is the setup of a control system enabling the hardware to perform these processes. Typically the larger amount of the available resources is needed for the setup of hardware and implementation of the required control mechanism, leaving only limited resources for the process development. Especially for small scale and prototype production with a high rate of changes, this is why fully automated solutions don't pay off and manual or partial manually assembly is preferred [1]. This paper introduces an approach how to separate the implementation effort of the hardware specific tasks from the process definition, allowing a fast and easy setup for new automation systems, due to simultaneous development and a high rate of reuse of previous solutions.
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