AF Mercados EMI

Ankara, Turkey

AF Mercados EMI

Ankara, Turkey
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Tulaz M.O.,AF Mercados EMI | Tor O.B.,METU - MEMS Center
NAPS 2011 - 43rd North American Power Symposium | Year: 2011

In a primary distribution network planning problem, determination of total number and size (i.e., additional total capacity) and siting of new distribution substations (DS) are among the first important tasks of planners who are responsible from supplying the loads securely, keeping the medium voltage level in defined limits and thereby minimizing losses. This paper presents a methodology to optimize total capacity and siting of new DSs based on spatial load forecast (SLF) results. Objective function minimizes total loss of the primary network while considering security constraints of the network. Given the proportionality between voltage drop and losses, the minimization of losses inherently takes into account minimization of voltage drops as well. First, a grid (250x250 m2) based distribution system is constructed on Microsoft Office (MS) Excel TM and based on a 10 year SLF assumption which takes into account different growth characteristics of the grids, all the loads are assumed to be supplied by the existing DSs along the planning horizon. Then, the proposed algorithm relaxes the overloaded DSs by placing pre-defined alternative DSs in an optimum manner while satisfying the network security constraints. © 2011 IEEE.


Lise W.,AF Mercados EMI | Lise W.,ECORYS Research and Consulting | Lise W.,Energy and Environment unit | van der Laan J.,Trinomics | van der Laan J.,Energy and Environment unit
Energy for Sustainable Development | Year: 2015

Climate change is expected to have impacts on the power sector, leading to, among others, a need for adaptation measures in the sector in the near future. This paper analyses the need to adapt to climate change impacts for power generation technologies in Europe until 2100. Europe is broadly divided into four geographic climate zones, for which regional climate change impacts are quantified with the help of the ENSEMBLES RT2b data. The European future technology mix is based on two Eurelectric energy scenarios: 'Baseline 2009' and 'Power Choices'. A Risk Assessment Model is formulated which assesses the cost to power plants for adapting to climate change. The analysis shows that thermal generation units most urgently need adaptation measures against floods, whereas off-shore wind power plants would need to take adaptation investments against sea level rise. Furthermore, electricity grids need to adapt to the increased incidence of storms. Finally, hydro generation in the Mediterranean regions needs to adapt to lower levels of precipitation. © 2015 International Energy Initiative.


Lise W.,AF Mercados EMI | Lise W.,ECORYS Research and Consulting | van der Laan J.,Energy and Environment unit | Nieuwenhout F.,Energy Research Center of the Netherlands | Rademaekers K.,Energy and Environment unit
Energy Policy | Year: 2013

Power system balancing will become increasingly important to secure a reliable European energy supply, as the share of intermittent supply increases (e.g. variable generation from wind and solar PV). This paper shows, in a quantitative way, the limitations of relying exclusively on flexibility in generation as the future shares of intermittent supply increase. Literature and data on intermittent supply and existing scenarios are reviewed. Costs related to increasing shares of intermittent supply are assessed. Quantifiable indicators relevant for electricity systems with a high share of intermittent supply are developed, namely (a) flexible supply (generation units that can quickly change output); (b) balancing need (which measures the needed flexibility of the power system as the difference between peak and off-peak residual demand (net of intermittent supply)). There is an externality of increasing the share of intermittent supply by increasing the power system balancing costs. If the cost of integrating intermittent generation was to be limited to about 25 billion EUR per year, which is an addition of 24% per unit intermittent generation cost, the intermittent supply share cannot reach more than 40% in the European power market. The final choice of an acceptable cost increase will be a political choice. © 2013 Elsevier Ltd.


Jana S.K.,Vidyasagar University | Lise W.,AF Mercados EMI | Lise W.,ECORYS Research and Consulting | Ahmed M.,Garhbeta College
Journal of Forest Economics | Year: 2014

This study analyses participation in joint forest management (JFM). The study is based on in-depth interviews with 150 households of Forest Protection Committees (FPC) in Paschim Medinipur district in the West Bengal state of India. Based on a Principal Component Analysis (PCA) of 14 participatory indicators, it follows that "social" aspects of participation are considerably less important in West Bengal than as found elsewhere in India, while the perception of the environment (first and third factor) stand out as the most important aspects of participation in JFM, jointly explaining almost half of the variance. Regression analyses indicate that household size, the number of forest committee meetings, religion of the household, willingness to pay of the household for the forest protection and the size of land holding are important variables for explaining variation in levels of participation. Results from estimating game theoretic models on participation among villagers in JFM indicates that in two out of the four possible situations, harmonious sharing of the benefits is an (Nash) equilibrium, but not unique. In all cases, institutional checks and balances are needed to guarantee mutual participation, which is possible only by strengthening the JFM management body. © 2014 Department of Forest Economics, Swedish University of Agricultural Sciences, Umeå.


Yorukoglu S.,AF Mercados EMI | Nasibov F.,AF Mercados EMI | Mungan M.,Ege University | Bagriyanik M.,Technical University of Istanbul
Conference Record - Industrial and Commercial Power Systems Technical Conference | Year: 2016

A portion of generated electrical power is lost in transmission and distribution systems while serviced to endusers. These losses are called technical and non-technical losses in electricity distributions systems. With privatization processes taken place over the world, huge debate arose regarding non-technical losses. In this study, information about types of losses in distribution systems, privatization process in Turkish electricity distribution network and current loss percentages are given. Possible alterations in distribution network topology to decrease non-technical losses are examined using analytical methods. Best methodology against non-technical losses is determined for different network topologies and customer characteristics, using AHP method. Choosing a pilot network, in which losses are considerably high, a case study is conducted. Cost-benefit analysis is performed within the scope of case study. Results of the case study indicate substantial potential for reducing non-technical losses by just altering network topology, where 1.6% reduction in overall T&L rates is estimated. © 2016 IEEE.


Tanidir O.,TUBITAK - Marmara Research Center | Cebeci M.E.,TUBITAK - Marmara Research Center | Gencoglu C.,AF Mercados EMI | Tor O.B.,TUBITAK - Marmara Research Center
International Journal of Electrical Power and Energy Systems | Year: 2012

Sufficient fast secondary reserve and its adequate dynamic activation are the key factors in satisfying automatic generation control (AGC) performance of a power system. Dynamic activation of the secondary reserves should also not introduce any negative damping to inter-area oscillations. This study presents a strategy to enhance AGC performance of a power system considering these concerns. Objective function is minimizing the amount of fast secondary reserves to mitigate ancillary service cost. The constraints are; AGC performance indices should be acceptable and AGC parameter settings should be adequate for inter-area oscillation concerns. In order to facilitate dynamic simulations, it is proposed to utilize a representative single bus common frequency dynamic model (SBCFDM) of the power system. The proposed strategy is based on optimizing the AGC parameters only for the time horizon when the loads are fluctuating most. Adequacy of the optimized AGC parameters are checked only for the worst loading scenario from inter-area oscillations concern point of view. It is showed that dynamic allocation of the secondary reserves twice a day is sufficient for satisfactory results. The proposed strategy is verified by its application to Turkish power system which suffers significant amount of fluctuating loads and inter-area oscillations with ENTSO/E grid. © 2012 Elsevier Ltd. All rights reserved.

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