Multiple causes of continuously occurring power outages in Yazd Province of Iran have been experienced in recent years. This research studies how key stakeholders have perceived the results of the strategic decisions taken by directors of HEPP to diminish the power shortages and to even increase power supply to a limit of exporting power to other neighboring provinces. How could HEPP emerge from an organization in the edge of bankruptcy to an organization that can surpass all expectations and won over their competitors? HEPP’s strategic decisions followed implications of several models and finally a strategic plan on the bases of the Bryson model was selected and practically applied to achieve their final expected results. The literature review in this study describes selected models as well as the Bryson model set up and structure. This study portrays a demonstration and an evaluation of various strategic plan management models used in Iranian organization in particular HEPP. The researcher designed several questionnaires and forwarded them to HEPP’s administrators, employees and other stakeholders in three groups. Additional phone interviews were conducted and the quantitative as well as qualitative data collected was evaluated and displayed in tables and figures in this study. Data analysis demonstrates a few shortcomings, weaknesses and strengths that are discussed in detail and conclusive proposals are presented through the conclusion section in enhancement of HEPP’s services to the advantages of stakeholders and employees of HEPP with a complete consideration for HEPP’s well being and awareness of its competitors. Although this study is limited in scope it highlights what needs to be done in HEPP or similar hydro electric organizations in Iran, and it can act as a stepping stone for further research and analysis of hydro electrical demand and supply issues in Yazd region of Iran.

In this thesis, a parametric methodology is investigated to design a Pump-Turbine system using Computational Fluid Dynamics ( CFD ). The parts of Pump-Turbine are created parametrically according to the experience curves and theoretical design methods. Then, these parts are modified to obtain 500 kW turbine working as a pump with 28.15 meters head. The final design of Pump-Turbine parts are obtained by adjusting parameters according to the results of the CFD simulations. The designed parts of the Pump-Turbine are spiral case, stay vanes, guide vanes, runner and draft tube. These parts are designed to obtain not only turbine mode properties but also pump mode properties.

Hovedopgave. / Format: PDF. Bibl.

Parts of the auxiliary power systems at Fortum's hydro power stations are usingdirect current, which is fed from the generators at the plant and converted byrectifiers. As photovoltaic solar cells produce direct current there are severalhypothetical advantages to use solar power for the auxiliary power supply, e.g.enabling more of the power from the generator to be sold to the grid. It eliminatesthe need of an inverter, conversion losses are avoided and less load is put on therectifiers. However the exclusion of an inverter also prevents the solar cells to have adirect connection to the grid, which in turn makes them ineligible for the Swedishgovernmental solar power investment support program. The lesser load on therectifiers will not affect their lifetime according to manufacturers and thus achieves noeconomic gain. Avoiding conversion losses will increase the gain from the producedelectricity by enabling even more power to be sold to the grid. The economic gainfrom avoiding conversion losses is however too small to gain any feasibility in a smallsolar power installation at a hydro power plant, as the small size will make itexpensive in terms of investment per Wp.

We consider a hydrothermal scheduling problem with a mid-term horizon(HTSPM) modeled as a large-scale multistage stochastic program with stochastic monthly inflows of water to each hydro generator. In the HTSPM we seek an operating policy to minimize the sum of present and expected future costs, which include thermal generation costs and load curtailment costs. In addition to various simple bounds, problem constraints involve water balance, demand satisfaction and power interchanges. Sampling-based decomposition algorithms (SBDAs) have been used in the literature to solve HTSPM. SBDAs can be used to approximately solve problem instances with many time stages and with inflows that exhibit interstage dependence. Such dependence requires care in computing valid cuts for the decomposition algorithm. In order to help maintain tractability, we employ an aggregate reservoir representation (ARR). In an ARR all the hydro generators inside a specific region are grouped to effectively form one hydro plant with reservoir storage and generation capacity proportional to the parameters of the hydro plants used to form that aggregate reservoir. The ARR has been used in the literature with energy balance constraints, rather than water balance constraints, coupled with time series forecasts of energy inflows. Instead, we prefer as a model primitive to have the time series model forecast water inflows. This, in turn, requires that we extend existing methods to compute valid cuts for the decomposition method under the resulting form of interstage dependence. We form a sample average approximation of the original problem and then solve this problem by these special-purpose algorithms. And, we assess the quality of the resulting policy for operating the system. In our analysis, we compute a confidence interval on the optimality gap of a policy generated by solving an approximation on a sampled scenario tree. We present computational results on test problems with 24 monthly stages in which the inter-stage dependency of hydro inflows is modeled using a dynamic linear model. We further develop a parallel implementation of an SBDA. We apply SBDA to solve the HTSPM for the Brazilian power system that has 150 hydro generators, 151 thermal generators and 4 regions that each characterize an aggregate reservoir. We create and solve four different HTSPM instances where we change the input parameters with respect to generation capacity, transmission capacity and load in order to analyze the difference in the total expected cost. / text

Uddevalla Energi AB äger fem vattenkraftstationer uppförda från 1920 och framåt. De är lokaliserade i Bäveån i Uddevalla kommun. Den totala installerade effekten i vattenkraftstationerna uppgår till omkring 2 MW. Vattenkraftstationen K4 Fossumsberg,vars installerade effekt uppgår till 1 MW, är den största utav anläggningarna ur denna aspekt. Utöver energiproduktion ska anläggningarna även svara för reglering av vattenståndet i Öresjö och i Bäveån. På uppdrag av Uddevalla Energi Elnät AB utförs detta examensarbete för att fastställa vilken utrustning som rekommenderas till kontrollanläggningarna för vattenkraftstationerna. De huvudområden som undersöks är generatorskydd, reglering, kommunikation och HMI. Krav från Uddevalla Energi Elnät AB ställs på olika skyddsfunktioner som exempelvi söverströmsskydd, jordfelsskydd, över- och underspänningsskydd, samt bakeffektskydd.Vidare önskas även att ny utrustning ska vara kompatibel med protokoll som stödjer MicroSCADA och har möjligheter för framtida användning av protokollet IEC 60870-5 för kommunikation mellan stationsutrustning och SCADA-systemet i driftcentralen. En rad produkter, varav ett flertal skulle kunna lämpa sig väl för ändamålen, undersöks från leverantörerna Schneider Electric, ABB och DEIF. Slutsatser dras bland annat om att Uddevalla Energi Elnät AB bör investera i separata enheter för reglering och för generatorskydd och inte kombinerade lösningar. Detta för att uppnå större säkerhet i händelse av fel i anläggningarna. Vidare konstateras att för att få ett komplett underlag att luta sig mot vid val av utrustning bör priser undersökas ytterligare, för att kunna väga in denna aspekt. / Five small hydroelectric power plants, constructed 1920 and later, are owned by UddevallaEnergi AB. The hydroelectric power plants are located in Bäveån in Uddevalla. The total installed power is approximately 2 MW. K4 Fossumsberg is the largest hydroelectric powerplant and has a production capacity of 1 MW. The hydroelectric power plants is not only used for energy production but also for regulation of the water levels in Bäveån and Öresjö. On behalf of Uddevalla Energi Elnät AB this bachelor thesis has been done to specify which equipment is preferable as the station monitoring and control equipment. The key areas ofthe report is generator protection, control and regulation, communication and HMI in the plants. There are demands from Uddevalla Energi Elnät AB regarding for instance overcurrent protection, earth fault protection, over- and under voltage protection and reversepower protection. Furthermore it is requested that the new station monitoring and controlequipment is compatible with MicroSCADA and has further options for using the protocol IEC 60870-5 for communication between station and the SCADA system used in the operating centre. Numerous products has been studied and many of them fulfil the requirements stated by Uddevalla Energi Elnät AB. The manufactures mentioned in this report are Schneider Electric, ABB and DEIF. Conclusions are made that Uddevalla Energi Elnät AB should invest in separate units for control and generator protection to achieve a higher level of safety in case of a fault in either generator protection or control equipment. Furthermore it is concluded that to obtain a more complete specification to use when choosing equipment one should consider the cost. More research is needed to take this into account.

Ce mémoire de maîtrise étudie l'histoire de la centrale nucléaire de Gentilly-1, située au Québec, proche de la ville de Trois-Rivières. Ce projet conjoint entre Énergie Atomique du Canada Limitée (ÉACL) et Hydro-Québec (HQ) s'est étalé du début des années soixante jusqu'au milieu de années quatre-vingt. Contrairement aux réacteurs canadiens classiques, modérés et refroidis à l'eau lourde, Gentilly-1 reposait sur un concept ayant recours à de l'eau bouillante légère comme refroidisseur. Cette particularité était supposée lui conférer une série d'avantages, notamment au niveau des économies de coûts d'exploitation qu'elle devait permettre. Si l'on était confiant, au sein d'ÉACL, en la faisabilité scientifique et technique du concept, il n'en demeurait pas moins que des incertitudes persistaient sur la capacité à contrôler un réacteur de ce type. Cette problématique allait ressurgir plusieurs fois, tout au long du déroulement du projet. En septembre 1966, à la signature du contrat pour la construction de la centrale, ÉACL voyait en Gentilly-1 un prototype pouvant servir de base au développement d'une nouvelle filière commerciale. Tandis que chez HQ, on y percevait le moyen de s'aguerrir à la technologie de l'atome dans la perspective de développer un programme électronucléaire autonome. Opérée à partir de novembre 1970, Gentilly-1 a cependant connu des problèmes chroniques de fonctionnement et n'a produit de l'électricité que de façon très sporadique. Après avoir vu son statut et ses objectifs plusieurs fois redéfinis, elle a été définitivement mise à l'arrêt en 1981 puis déclassée en 1986. Si l'expérience de Gentilly-1 est communément considérée comme un « échec technologique », il apparait évident qu'au-delà des problèmes techniques rencontrés, des facteurs sociopolitiques, économiques et commerciaux ont également fortement influencé le déroulement du projet. L'analyse de ces facteurs permet de faire du projet Gentilly-1 une histoire qui dépasse le simple cadre technique et qui englobe des enjeux beaucoup plus vastes. Elle démontre également l'importance de la prise en compte des facteurs contingents dans les trajectoires que prennent les grands projets technologiques. ______________________________________________________________________________ MOTS-CLÉS DE L’AUTEUR : Gentilly-1, ÉACL, Hydro-Québec, Nucléaire, Québec, Innovation, Échec technologique.

Šiuo magistriniu darbu mėginsiu išsiaiškinti mažosios hidroenegetikos vystimosi galimybes, palyginti jas su kitomis elektrinėmis, išsiaiškinti kokius upių resursus turi mūsų šalis, kokie yra gamtosauginiai reikalavimai hidroenergetikoje, generatoriai, kokie yra hidroelektrinės prijungimo prie tinklo variantai. / The theme of Master project of Electrical engineer is The investigation of potentiolity development of small hydro energetic. I think it is very important, because Lithuania is going to close Ignalina nuclear power station as it is required by the EU. Obviously, we are forced to find solution of energy shortage. One of the solutions are renewable energy sources. Lithuania has potential power in rivers and it has opportunity to expand of small hydro energetic. Byt we have to admit, that nowadays a small hydro energetic is not expanding as fast as it could. In my Master project of electical Engineer I show, how easy is to construct hydro power station, but hard to find a place, where station could be, to conect it with electricity networks for several reasons.

Electric power is a basic requirement for present day life and its various economic sectors. To satisfy the ever-increasing needs for electricity, the number of generating units, transmission lines and distribution systems is rising steadily. In addition, electric power systems are among the most complex industrial systems of the modern age. Beside complexity, the generation of electric power is a main source of gaseous emissions and pollutants. The planning and operation of electric power systems must be done in a way that the load demand is met reliably, cost-effectively and in an environmentally responsible manner. Practitioners strive to achieve these goals for successful planning and operations utilizing various optimization tools. It is clear that the objectives to be satisfied are mostly conflicting. In particular, minimizing the fuel cost and the gaseous emissions are two conflicting and non-commensurate objectives. Therefore, multi-objective optimization techniques are employed to obtain trade-off relationships between these incompatible objective functions in order to help decision makers take proper decisions. In this thesis, two main power system operation problems are addressed. These are the economic load dispatch (ED) and the short-term hydro-thermal generation scheduling (STHTS). They are treated first as single-objective optimization problems then they are tackled as multi-objective ones considering the environmental aspects. These problems, single and multi-objective, are nonlinear non-convex constrained optimization problems with high-dimensional search spaces. This makes them a real challenge for any optimization technique. To obtain the optimal or close to optimal solutions, a modified bacterial foraging algorithm is proposed, developed and successfully applied. The bacterial foraging algorithm is a metaheuristic non-calculus-based optimization technique. The proposed algorithm is validated using diverse benchmark optimization examples before implementing it to solve the problems of this thesis. Various practical constraints are considered in the different cases of each problem. These include transmission losses, valve-point effects for both the ED and the STHTS problems and water availability and reservoir configurations for the STHTS problem. In all cases the optimal or near-optimal solution is obtained. For the multi-objective optimization cases, the Pareto optimal solution set that shows the trade-off relationship between the conflicting objectives is successfully captured.

The lower Churchill River has been an important travel route for people living in its vicinity for a long period of time. Churchillians’ have used it for subsistence harvesting, as their potable water source and as a place of recreation and relaxation. Previous research has documented the importance of the Churchill River to the residents and has explored how the Churchill River Diversion affected the community of Churchill (Boothroyd, 1992; 2000; Four Directions Consulting Group, 1994; 1995). The purpose of this project was to identify how Churchill residents used the lower Churchill River (from 1970 to 2006), recognizing three distinct periods of time. Twenty interviews were conducted with former or current long-term residents of Churchill, as well as two interviews with experts on issues concerning the lower Churchill River. Many interviewees stated that additional negotiations and measures are required before they deem the mitigation compensation package from Manitoba Hydro to be adequate considering the impact of the diversion on the residents of Churchill.