Creg Uploaded by. Alexandra Rico. Loading Preview. Sorry, preview is currently unavailable. You can download the paper by clicking the button. resolucion creg de pdf merge. Quote. Postby Just» Tue Aug 28, am. Looking for resolucion creg de pdf merge. Will be grateful. This CREG Regulation establishes the following articles: The connection to to the network backup: CREG Resolution / – Energy supply: through a.
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Such rules were defined in an incentives and compensations scheme aimed at stimulating the ongoing improvement of reliability. However, this study assumes that the capacities of the DG plants adequately represent the peak demand of the respective plant owner customers, which is a more realistic situation.
Based on the results of the incentives scheme shown in Table 4, it was possible to observe that without DG in crey system, the electric utility neither receives financial benefits nor should pay financial penalties, because it is located in the dead zone of the incentives curve.
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On the other hand, the following variables are calculated: Additionally, OMS has an integrated power flow to analyze the distribution network in real time.
The estimated values of the 0977 cost of electricity service described in Table 6 were the same for all passive customers, because these customers were connected to the same voltage level.
The purpose of this analysis is to explain that, the DG interconnection in distribution systems may cause crsg the energy bill of passive customers increases or decreases, with respect to the operation scheme without DG. The penalty increases as performance worsens and it is capped when a maximum penalty is reached. Finally, each operation scheme for the DG interconnection which it is desired to evaluate is simulated.
We proceed to determine the faulty component as the one with the lowest Tf. Studying and comparing the incentives and compensation due to the reliability supplied, for the two operation schemes with and without DG.
An in-line transformer reducing the voltage to 4. The capacities of these generation sources allow supplying the total demand of the distribution system in a fault condition in the power system.
This model is equivalent to a continuous time process for a repairable component, and it is constructed from historical information about output events and their corresponding reconnection times. This analysis is presented in Table 4.
The fault condition for a load point is defined if: This negotiation represents a very adequate and fair option for such customers, because they are who would improve the reliability by using their DG units as backup plants.
Electrical Model of Components and Demand: If reliability is worse than the dead zone boundary Z2a penalty is assessed. This is because the application of the incentives and compensations scheme would cause some increases in the electricity bill of passive customers, which would be higher than the reductions in the bill due to the CU dg in most of the technologies is lower than the RC.
It is also used as reference, state diagrams, logic diagrams, etc, depending on the case and accuracy required. The bonus grows as reliability improves and it is capped at a maximum value. For each scheme, it is necessary to model the distribution system considering three ceg Next, the assessment periods of the reliability supplied by electric utility 907 its customers were simulated.
The results presented in Table 5 were evaluated with the following two assumptions:. How to cite this article. Energy supplied by power system. Spanish pdf Article in xml format Article references How to cite this article Automatic translation Send this article by e-mail.
resolucion creg 097 de 2008 pdf merge
In order to carry out the implementation of this study, it was necessary as a first step to bring up a simple key analysis for evaluating the results of the comparative method, which is shown in Figure 7.
English pdf Article in crg format Article references How to cite this article Automatic translation Send this article by e-mail. Reliability Model of Components: However, when a fault occurs in the system and consequently the power supplied to some customers is interrupted, the DG supplies electricity to those customers depending on the vreg location, and the relationship between the DG installed capacity and the power demanded by such customers.
The economic savings in the energy bill of each one of the customers who would install DG units. Then, the assessment periods of the reliability supplied by electric utility to its customers are simulated. Finally, it applies this methodology to a distribution system and it identifies regulatory strategies when DG interconnection is not profitable. According to the results presented of the comparative method, it was concluded that for passive customers it is more profitable to connect DG sources whose installed capacities do not produce very strong improvements in the reliability supplied by the electric utility.
resolucion creg 097 de 2008 pdf files
The results of this analysis are presented in Table 3. For simulating the first assessment period, the iterative simulation procedure was applied for the same operation scheme without DG which was executed for years of analysis. This information is presented in Table 6. The results obtained from the comparative study led to deducing that the interconnection of the DG units described in the first study whose technology was any of the analyzed would imply increases in the estimated annual electricity bill of passive customers, regarding the operation scheme that does not consider the DG interconnection.
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It was also noted that the installation of the DG units described in the first study, corresponding to customers crg, and and whose technology is photovoltaic would not be profitable, because they exceed the defined maximum time to recover the initial investment. On the other hand, despite the incentives and compensations scheme allows smaller variations in the bill behavior of passive customers, its application is constant.
Regarding the compensations scheme, it was possible to observe that without DG in the system, the electric utility should compensate its ”worst served” customers through the electricity bill, with an expected annual compensation of 3.
On the other hand, the ITAD behavior for the first study was fitted to a gamma function of probability density.
The proposed methodology was applied to an IEEE test distribution system, considering different operation schemes for the distributed generation interconnection.
Methodology for assessing the impacts of distributed generation interconnection. Considering an n-1 contingency level and assuming that the system is operating normally, it is generated for each system components a random number between 0 and 1 from a uniform distribution for that range.
However, when DG units are connected, a large part of the ENS will be supplied by the rceg generation sources cret to the system and it will be billed to customers through the unit cost of electricity service from DG units CU dg.
The incentives and compensations scheme CREGdescribed in section II, which promotes the improvement in the reliability supplied by electric utility.
The scheme so described is presented in Figure 1. The ITAD reliability index and the incentives and compensations scheme adopted in the methodology are not evaluated quarterly as described in section II, but annually.
These results allow through a balance between performance and costs, contribute to feasibility studies for DG interconnection in customer installations. The simulation will advance from the reference moment to the Tf of the faulty component. The application of the second study would bring small reductions in the estimated value of the ITAD reliability index, regarding the reference conditions offered by the dead zone. NSGA II algorithm; multiobjective optimization; relocation of distribution transformers; distribution systems.