In this work, the accurate representation of transmission lines for the digital simulation of electromagnetic transients in power systems has been examined. A model has been developed that accounts for the frequency dependence and distributed nature of the line parameters over the entire frequency range. This model can easily be incorporated into a time-domain network solution of the complete power system. The model consists simply of a constant resistence in parallel with a current source evaluated at each time step of the solution. The equivalent resistance results from a finite-step-width discretization of the differential equations of a resistance-capacitance (R-C) network that simulates the line characteristic impedance. The equivalent current source accounts for the time delays and attenuations of the different frequency components of the travelling waves and for the discretization of the time-domain equations. Rational-function approximations are used to synthesize the R-C network and the line propagation ("weighting") function in the frequency domain. These rational approximations allow the corresponding time-domain functions to be obtained directly in a closed-form, thus circumventing the need for numerical inverse Fourier transformations. The numerical technique used to obtain the rational functions yields very accurate, high-order approximations. This technique is based on a direct, step-by-step allocation (and reallocation) of poles and zeros and avoids the instability problems which can be encountered with optimization techniques based on search methods. A series of analytical evaluations and simulation tests were performed in order to assess the validity of the model. The results of these tests show that the model is accurate, fast, and reliable. The model was incorporated into the code of the University of British Columbia's version of Dr. H.W. Dommel's Electromagnetic Transients Program (EMTP). i / Applied Science, Faculty of / Electrical and Computer Engineering, Department of / Graduate

This thesis presents findings of experiments conducted to determine the most feasible method to electroplate metal.

No description available.

No description available.

No description available.

$$Saudi Arabia faces a challenging path to generate the electricity needed to keep growing while lowering its annual emissions. The emissions from electricity generation have grown significantly due to the rising electricity demand per capita and the abundant use of liquid fuels for electricity generation. The high demand is driven by the comparatively low costs of electricity, whereas the consumption of liquid fuels for generation is driven by the distorted market caused by strong subsidies for these fuels. By 2030, in a scenario free of reforms, liquid fuels would provide more than half of the fuel energy consumed for generation and would emit around 64% of the emissions. However, they would only represent 10% of the fuel costs at a domestic price. In this work, the effect and pertinence of reforms to the electricity price and to the fuels consumed for generation are addressed. Tariffs for countries with similar size of economy are taken as a reference. We found that raising the electricity price to international tariffs could reduce the demand projections for 2030 by up to 9%. Being the industrial sector more sensitive to price changes than the residential sector. The distortion between fuel price and consumption could be adjusted by increasing the domestic fuel prices to 30% of the international reference, which affects mainly liquid fuels. In this scenario, photovoltaic panels (PV) become a competitive substitute for gas turbines (GT). However, renewables would not exceed 43% of the total capacity and 28% of the energy generated without the early retirement of firm capacity. The resulting cost of emissions avoided by reforming fuel prices is of $43/ton CO2eq. Simultaneously reforming electricity prices and fuel prices would favor the penetration of renewables without additional costs of investment. Besides, the marginal cost of electricity would remain close to $45/MWh. Finally, reforming the price of fuel and exporting the saved fuel would derive in additional revenue of up to $6.6 billion by 2030, and would reduce the annual emissions by 2030 by up to 66 million tons of carbon dioxide. The economic gain from exporting the fuel saved by 2030 would be enough to relieve the additional cost in the electricity bill to the residents which represent 73% of the total consumption, through social programs.

<p> Three chapters comprise this project. The first chapter deals with the global picture of energy supply and demand, and concludes that other sources of energy must be developed in the next fifty years.</p> <p> Chapter Two considers a number of alternate sources of energy and examines two sources in particular: (i) Hydrogen and its dependence on electricity, and (ii) Nuclear energy used to produce electricity. Certainly, Ontario has a very viable option to produce electricity by means of nuclear energy.</p> <p> Home heating can, to some extent, be controlled by the individual, and Chapter Three discusses the operation of a heat pump and its feasibility as a heating device for homes in the Southern Ontario climate.</p> / Thesis / Master of Science (Teaching)

No description available.

Prior to 1996, roughly 70% of electricity service in California was provided by investor owned utilities (IOUs). The IOUs operated as monopolies in their respective service territories, performing all of the functions necessary to generate and deliver electricity to the consumer. In exchange for service, the IOUs were paid a regulated rate which was designed to recover their cost of providing the service plus a reasonable return on their investment. In 1996, California changed the way electric service was provided in order to make it more competitive. Among the changes, utilities would procure their supplies at market prices in an auction or spot market; residential customers could choose their electric supplier; and residential rates were frozen at 10% below their June 1996 levels. The rate freeze was to remain in effect until the later of March 31, 2002, or the date the IOUs fully recovered certain expenses that were still on their books (i.e., stranded costs). The restructured market commenced operations on March 31, 1998. During the summer of 2000, California experienced record increases in wholesale prices and supply shortages that ultimately resulted in a number of rolling blackouts. Most of California?s residential customers were unaffected by the increased wholesale prices because their rates remained frozen. Regulators and others who have studied what went wrong during the summer of 2000 in California agree that the increase in wholesale prices was due to a combination of factors, one of which was the residential rate freeze. This thesis proposes to show how fixing the price of electricity resulted in excess demand and to quantify the size of the excess. This thesis also shows how much of a price increase would have been needed to prevent the shortages. / Master of Arts

Carbon tax, increased reactive power charges, tariff increases and the Energy Conservation Scheme (ECS) are some of the worrying electricity cost risks faced by large South African industries. Some of these proposed cost risks are not enforced as yet, but once approved could threaten company financial viability and thousands of jobs. Managing multiple cost risks associated with electricity consumption at several mines can be laborious and complex. This is largely due to circumstantial rules related to each potential electricity cost risk and unique mine characteristic. To limit the electricity cost risks for a mining company, clear strategies and focus areas need to be identified. No literature was found that provides a simplified integrated electricity cost risk and mitigation strategy for the South African gold mining industry. Previous studies only focused on a single mine or mining subsystem. Literature pertaining to potential risks is available, however the exact impact and mitigation on the gold mining industry has yet to be determined. The aim of this study is to accurately predict the impact of electricity cost risks and identify strategies that could alleviate their cost implications. Electricity consumption and installed capacities were used to benchmark mines and categorise them according to investigated risks. The benchmarked results provided an accurate starting point to identify best practices and develop electricity cost saving strategies. This study will highlight the additional benefits that can be obtained by managing electricity usage for a group of mines or mining company. Newly developed models are used to quantify savings on pumping, compressed air and cooling systems. To manage and report on the potential risks and mitigation, an ISO 50001 based energy management system was developed and implemented. The applied and developed models can also be adjusted to review and manage the potential cost risks on other types of mines. Derived risk and mitigation models were further used to quantify the impact on one of the largest gold mining companies in South Africa. These models indicate a potential annual price increase of 12%, while mitigation strategies could reduce the electricity consumption by more than 7%. Mitigation savings resulted from proposed projects as well as behavioural change-induced savings due to improved management. Over a five-year period the projects identified could result in electricity costs savings of between R675-million and R819-million. / PhD (Electrical Engineering), North-West University, Potchefstroom Campus, 2014