Please use this identifier to cite or link to this item: https://hdl.handle.net/10356/73173
Title: Power system adequacy and cost/worth assessment incorporating virtual power plants
Authors: Bagchi, Arijit
Keywords: DRNTU::Engineering::Electrical and electronic engineering::Electric power
Issue Date: 2018
Source: Bagchi, A. (2018). Power system adequacy and cost/worth assessment incorporating virtual power plants. Doctoral thesis, Nanyang Technological University, Singapore.
Abstract: A variety of factors such as the emergence of novel business models in deregulated power markets, adoption of smart grid technologies, economic recession as well as climate change has led to a proliferation of distributed energy resources (DER) in low and medium voltage power networks over the last decade. The DER portfolio can consist of any given combination of renewable and/or conventional source based distributed generators (DG), energy storage devices (ESD) as well as controllable loads. Today’s distribution networks are therefore gradually getting transformed from their traditional ‘passive’ roles to an ‘active’ system featuring advanced coordination and control of its constituent DER components and protection equipment. Indiscriminate addition of DERs on the demand side, however, poses a number of visibility and security related challenges for the system operators, primarily owing to the modest capacities most DERs possess (a few kW to a few MW) coupled with the inherent intermittencies associated with renewable resources. The concept of aggregating several active distribution network components like DERs and loads in the form of a virtual power plant (VPP) has therefore often been proposed for tackling the above mentioned challenges. In the available literature pertaining to the reliability evaluation of power systems incorporating VPPs, the system studies are all carried out at the distribution network level, meaning that they fail to quantify the average energy that the VPP can export to the transmission grid after meeting local distribution network demands and constraints. Additionally, the evaluation of system reliability at the distribution level does not adequately portray the possible improvements which can be brought about in the overall system reliability due to the injection of excess energy into the external grid by the VPP. Moreover, a holistic planning approach for determining an optimal DER portfolio for the VPP so as to minimize its total operating, investment and interruption costs while considering transmission network constraints and contingencies has not been explored. This thesis addresses these limitations by proposing generic methodologies for performing generation and bulk power system adequacy and cost/worth assessments incorporating VPPs. The first contribution of this research work is the proposal of a Monte Carlo simulation based methodology for performing adequacy assessment of generating systems incorporating VPPs. The disparate operating characteristics as well as capacities of individual DGs and local loads along with information about distribution network features like topology and constraints are combined together to form an equivalent model of a VPP using a linearized network flow based optimization formulation. The VPP is mathematically represented as a single entity with respect to the transmission grid, and it’s ‘prosumer’ (producer/consumer) characteristics are portrayed using a probability density function. The equivalent VPP model is used in conjunction with several new indices introduced for quantifying different aspects of the VPP’s performance. Key reliability indices are presented for quantifying the VPP’s contributions in improving overall system reliability. A general methodology for investigating the impacts of incorporating ESDs into the VPP model mentioned above, and subsequently using this model for performing generation adequacy studies is proposed next as the second contribution of this research work. A linear programming based multi-stage optimization formulation is presented for combining the stochastic hourly-output based models of several DGs, ESDs and loads along with distribution network features like topology and constraints into an aggregated probabilistic representation of the VPP. Several modes pertaining to the charging/discharging of the distributed ESDs are integrated with the formulation using a fair energy allocation based operating strategy. The VPP performance indices mentioned above are suitably modified for quantifying the impacts of the ESDs’ incorporation into the VPP profile. A systematic procedure is introduced as the third contribution of this research work for assessing bulk power system adequacy incorporating the equivalent VPP model (including ESDs) developed above. A linearized DC load flow based optimal power flow (OPF) formulation is proposed for performing transmission network contingency analysis. The OPF problem minimizes the total load curtailment and generation costs for the system, while also enabling priority dispatch of the VPP output (if available) into the external grid. The VPP performance indices are suitably modified for highlighting the impacts of transmission grid constraints and contingencies on the VPP profile, and it is shown that the severity of these impacts is a function of the VPP’s location in the transmission grid under consideration. The effects of the VPP’s incorporation on reliability at the system and at individual transmission bus levels are also quantified using key bulk power system adequacy indices. The DC load flow based OPF formulation described above is then combined with composite system cost/worth analysis techniques for determining an optimal DER portfolio for the VPP so as to minimize the total perceived costs pertaining to the VPP’s participation in day-ahead electricity markets. This constitutes the fourth and final contribution of this research work. The costs associated with the VPP are sub-divided into five categories – import, customer interruption, operation, investment and revenues – and different DER configurations are examined to determine the optimal portfolio which offers the highest cost savings for the VPP aggregator. Depending on the VPP’s location in the transmission grid under consideration, the performed simulations demonstrate that the optimal DER portfolio offers the VPP aggregator an estimated cost savings in the range of 414.69 k$/year – 620.92 k$/year. The overall methodologies proposed in this thesis are tested using the Roy Billinton Test System (RBTS) as well as the IEEE Reliability Test System (RTS). Two distribution network test beds are separately used for modelling the VPP: the RBTS Bus 4 distribution network and the (larger) IEEE 69- bus distribution network. Sequential Monte Carlo techniques are employed for performing the simulations. Extensive sensitivity studies are performed and several extensions to the work done in this project are listed as potential areas of future research. The results presented in this thesis can not only provide valuable information to the VPP aggregator and the system operator regarding important facets of the VPP’s performance, but also offer them critical insights pertaining to the economic benefits which can be obtained from incorporating VPPs into existing power networks.
URI: http://hdl.handle.net/10356/73173
DOI: 10.32657/10356/73173
Schools: School of Electrical and Electronic Engineering 
Fulltext Permission: open
Fulltext Availability: With Fulltext
Appears in Collections:EEE Theses

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