Triplett J.,Power System Engineering Inc. |
Rinell S.,Otsego Electrical Cooperative Inc. |
Foote J.,Otsego Electrical Cooperative Inc.
Papers Presented at the Annual Conference - Rural Electric Power Conference | Year: 2010
Distribution system losses are a reality due to the physics associated with various system components that make up any power system. Techniques for analyzing losses are not new but have primarily focused on evaluating system losses during certain peak demand periods due to limitations on available data. Such "traditional" analyses estimate energy losses using industry accepted approaches that rely heavily on assumptions and that focus only on peak and average demands on major system components. Another potential shortcoming of a traditional loss analysis is the level of system detail evaluated. A gross analysis in terms of system components such as substation power transformers, distribution lines, distribution transformers, secondary conductors, etc. is typical. The disadvantage is that the relative contribution of various system components to the overall system losses may not be defined to the level required to truly evaluate mitigation techniques, especially when time periods other than peak demand times are being evaluated. Given the limitations of traditional loss evaluations, this paper will explore enhanced loss evaluation techniques utilizing interval load data collected from a deployed Advanced Metering Infrastructure (AMI) system and detailed system data from an available Geographic Information System (GIS). The test case system used to present this approach was a distribution cooperative with these systems presently in place. © 2010 IEEE. Source
Kufel S.A.,Power System Engineering Inc.
Papers Presented at the Annual Conference - Rural Electric Power Conference | Year: 2015
The number of applications for Distributed Generation (DG) interconnections received by utility system operators is increasing every year. As the various DG technologies mature and the cost per kilowatt of generation goes down, utilities may receive more applications for generation interconnections large enough to require detailed system impact analysis before approval. Many utilities are already performing their own system impact studies, or are planning to begin doing so in the near future. A number of computer-based analysis programs are available that can model generation resources, with varying degrees of complexity. Utilities that are already performing their own studies need to be completely familiar with all of the capabilities of the particular tool or tools they use, and should have a reliable procedure in place for performing their analyses. This paper will examine the process of performing a DG system impact study with a computer-based system modeling tool. Topics of discussion will include information and data needed for accurate modeling, using various types of generator models, correctly adding generation to existing models, types of analysis that should be performed, common errors in modeling and analysis, and general best practices for completing system impact studies. Practical experience gained from performing many DG studies for utilities using several widely-available modeling tools will be shared. © 2015 IEEE. Source
Jeffrey M. Triplett P.E.,Power System Engineering Inc.
Papers Presented at the Annual Conference - Rural Electric Power Conference | Year: 2014
Distributed Generation (DG) interconnections with utility systems are becoming increasingly common. After a DG application has been processed, all needed studies completed and any required interconnection facilities constructed to accommodate the safe and reliable parallel operation of the DG facility, testing and commissioning is required. This paper will describe typical inspection, testing and commissioning procedures for a range of DG installation sizes and types. Practical experience gained from real-world installations and best practices for utilities will be shared in the form of a sample check list and procedure for smaller inverter-based systems. © 2014 IEEE. Source
Triplett J.M.,Power System Engineering Inc. |
Kufel S.A.,Power System Engineering Inc.
Papers Presented at the Annual Conference - Rural Electric Power Conference | Year: 2012
Conservation Voltage Reduction (CVR) has been a hot topic in the industry for some time, particularly during the last few years. A number of methods and strategies have been employed on utility distribution systems to effectively lower the voltage with the objectives of decreasing coincident peak demand and/or energy over time. © 2012 IEEE. Source
Chen S.,University of Maine, United States |
Onwuachumba A.,University of Maine, United States |
Musavi M.,University of Maine, United States |
Lerley P.,Power System Engineering Inc.
Clemson University Power Systems Conference, PSC 2016 | Year: 2016
In order to assess the reliability of power systems, System Planners must conduct both steady-state and stability simulations. The transient stability simulation of the reliability studies usually involve extensive variations and thus generate large amounts of data. Conventional analysis methods include visual examination of the simulation data plots to classify the severity of disturbances, objectively decide to apply the logical relationships between criteria. This paper, presents a quantification method for power system performance to achieve a more efficient stability analysis assessment. By using a criteria function matrix and a logic matrix, the proposed method evaluates the performance of each contingency and dispatch numerically and gives the overall stability assessment result. Damping and voltage sag criteria functions are applied for identification of the worst fault. This method will free engineers from tedious, time consuming and error-susceptible offline visual analysis and yield significantly more objective and quantified results. © 2016 IEEE. Source