Transactive energy (TE) has been recognized as a promising technique for integrating responsive loads and distributed energy resources as well as advancing grid modernization. To help the industry better understand the value of TE and compare different TE schemes in a systematic and transparent manner, a comprehensive simulation-based TE valuation method is developed. The method has the following salient features: first, it formally defines the valuation scenarios, use cases, baseline, and valuation metrics; second, an open-source simulation platform for transactive energy systems has been developed by integrating transmission, distribution and building simulators, and plugin TE and non-TE agents through the framework for network cosimulation (FNCS); third, transparency and flexibility of the valuation is enhanced through separation of simulation and valuation, base valuation metrics, and final valuation metrics. A valuation example based on the smart grid interoperability panel use Case 1 is provided to demonstrate the developed TE simulation program and the valuation method.

Quasi-static time-series (QSTS) simulation is used to simulate the behavior of distribution systems over long periods of time (typically hours to years). The technique involves repeatedly solving the load-flow problem for a distribution system model and is useful for distributed energy resource planning. When a QSTS simulation has a small time step and a long duration, the computational burden of the simulation can be a barrier to integration into utility workflows. One way to relieve the computational burden is to simplify the system model. The segment substitution method of simplifying distribution system models introduced in this paper offers model bus reduction of up to 98% with a simplification error as low as 0.2% (0.002 p.u. voltage). In contrast to existing methods of distribution system model simplification, which rely on topological inspection and linearization, the segment substitution method uses black-box segment data and an assumed simplified topology.

Modern electric power distribution systems are data rich and include growing numbers of distributed energy resources and distribution automation. To take advantage of distribution automation and manage growing penetrations of distributed energy resources, distribution utilities need applications for planning and operations that use all available data and may incorporate distributed approaches to operate and control. The industry would benefit from distribution management applications based on a common platform that makes systems of each type interchangeable. This paper describes an approach to enabling cost-effective development and deployment of advanced applications for distribution system planning and operations based on development of an open-source, standards-based platform for application development called GridAPPS-D, which leverages data abstractions for application development based on standards, such as the distribution system common information model.

Identifying the exact fault location within a HVDC system is critical in order to perform rapid system restoration for enhanced system reliability and operation. A method is proposed to locate faults using transient system data generated by the fault with system measurements at the HVDC converter terminals. The proposed method can locate temporary and permanent faults on a hybrid HVDC-VSC system, where the transmission medium consists of long segments of both underground cable and overhead line. The proposed routine is based on modeling the behavior of the traveling wave and making use of Rogowski coils for measurements.

For many years, an IEEE program called Flash was maintained to estimate flashover rates on transmission lines. With recent consolidation of two Working Groups, a new version of Flash has been developed to consistently treat both transmission and distribution lines. The new software includes line arresters, shield wires, tower and pole grounding, and insulation added by wood or fiberglass. The program also incorporates electromagnetic transient simulation. Examples from transmission and distribution lines are presented.

Objectives Delay in treatment of testis cancer (TC) has a proven negative impact on disease stage, treatment outcome, and mortality. Poor public awareness of the disease and lack of testis self-examination (TSE) may account for late presentation. The aim of this study was to examine the knowledge of TC and performance of TSE in a group of men over 2 time periods 20 years apart. Methods In the current study, 677 men from a banking institution were surveyed on their knowledge of TC and their performance of TSE. Comparisons were made from the current data and those from the original study in 1986. Results This study demonstrates an increase in public awareness and modest concomitant increase in TSE since first studied in this country in 1986. There was no difference in knowledge across age groups in this study. Furthermore, men who demonstrate a superior degree of knowledge were more likely to perform TSE. Limitations included possible selection bias in the 2 studies conducted in a banking institution. Conclusions Increased testicular cancer knowledge combined with TSE may have a role in improving detection of significant testicular pathology.

The Utility Wind Interest Group (UWIG) has undertaken a Distributed Wind Impacts project, which has produced software tools, application guides, and case studies to evaluate distributed wind projects. The project size may range from 1.5 to 15 MW, or higher in the near future. Given a number and size of available utility-scale wind turbines, and a candidate site, the evaluation process follows these high-level steps: 1. Capacity factor estimate from wind speed and other site characteristics. 2. Determine financing and power purchase agreement options. 3. Estimate the maximum feeder voltage change from full-on to full-off operation. 4. Electrical island evaluation from load and wind generation profiles; determine the need for transfer trip or other mitigation. 5. Flicker screening from the substation transformer size, type of line conductor, and distance from the substation. 6. Using a more detailed feeder electrical model: a. Estimate the loss of sensitivity in detecting ground faults with resistance. b. Check for proper coordination of the feeder overcurrent protective devices. c. Check for proper operation of utility tap changer and capacitor switching controls. 7. Design the interconnection, including transformer winding connections and wind turbine generator protection settings, to meet IEEE Std. 1547 and regulatory requirements. 8. Post-installation monitoring and evaluation, focusing on energy production and flicker. The methodology has been applied to several distributed wind projects, and these results are presented as case studies. The method is also presented at an annual workshop co-sponsored by National Renewable Energy Laboratory (NREL), American Public Power Association (APPA), National Rural Electric Cooperative Association (NRECA), and Western Area Power Administration (WAPA).

The electric power distribution system usually operates in a radial configuration, with tie switches between circuits to provide alternate feeds. The losses would be minimized if all switches were closed, but this is not done because it complicates the system's protection against overcurrents. Whenever a component fails, some of the switches must be operated to restore power to as many customers as possible. As loads vary with time, switch operations may reduce losses in the system. Both of these are applications for reconfiguration. The problem is combinatorial, which precludes algorithms that guarantee a global optimum. Most existing reconfiguration algorithms fall into two categories. In the first, branch exchange, the system operates in a feasible radial configuration and the algorithm opens and closes candidate switches in pairs. In the second, loop cutting, the system is completely meshed and the algorithm opens candidate switches to reach a feasible radial configuration. Reconfiguration algorithms based on linearized transshipment, neural networks, heuristics, genetic algorithms, and simulated annealing have also been reported, but not widely used. These existing reconfiguration algorithms work with a simplified model of the power system, and they handle voltage and current constraints approximately, if at all. The algorithm described here is a constructive method, using a full nonlinear power system model that accurately handles constraints. The system starts with all switches open and all failed components isolated. An optional network power flow provides a lower bound on the losses. Then the algorithm closes one switch at a time to minimize the increase in a merit figure, which is the real loss divided by the apparent load served. The merit figure increases with each switch closing. This principle, called discrete ascent optimal programming (DAOP), has been applied to other power system problems, including economic dispatch and phase balancing. For reconfiguration, the DAOP method's greedy nature is mitigated with a backtracking algorithm. Approximate screening formulas have also been developed for efficient use with partial load flow solutions. This method's main advantage is the accurate treatment of voltage and current constraints, including the effect of control action. One example taken from the literature shows how the DAOP-based algorithm can reach an optimal solution, while adjusting line voltage regulators to satisfy the voltage constraints. Special thanks are due to my wife, Kathleen Retcofsky McDermott, for her patience and understanding during my pursuit of this degree.