First,we discussed the profile of global project finance,including definition,model,and structure of project finance.Second,we discussed the situation on power plant industry.Third,we compare the difference of highway and power plant.We used a lot tables and charts on our essay.Fianlly,we consider that power plant should be suitable on project finance.And Boo is the better development model.

In high-level automation industrial processes where maintenance or repair can not be carried out immediately, it is important to design autonomous controllers capable of maintaining the performance, reliability and safety of plants operating under sensor, actuator faults and failures, equipment fouling, feedstock variation. Advanced control strategies such as Active Fault Tolerant Control (AFTC) have been used to accommodate system failures automatically. This research presents an AFTC methodology using model predictive control (MPC) combined with a bank of Kalman Filters. This hybrid fault tolerant control system are testing in a linearized 14-order boiler-turbine unit to deal with sensor faults and actuator faults. When sensor fault occurs, the virtual sensor techniques, which uses both a bank of Kalman Filter and a reconfigured Kalman Filter is applied to estimate the plant state and corrupted sensor value. The reconfigured MPC controller, which has naturally ability in dealing with output and actuator constraints, is equipped with some advanced capabilities such as online parameter tuning mechanism, the stability improvement techniques, the feasibility improvement techniques and reference management technique to handle the plant actuator faults. In case of some specific actuator faults, the MPC controller is restructured to deal with the faults better. The proposed fault tolerant control successfully recovers the system performance in the sensor fault cases and some of the actuator cases. In other fault cases, where the system performance recovery is impossible due to faults, the fault tolerant control degrades the system performance to keep the system stable. / text

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Uncertainty can be either an opportunity or a risk. Every construction project begins with the expectation of project performance. To meet the expectation, construction projects need to be managed through sound risk assessment and management beginning with the front-end of the project life cycle to check the feasibility of a project. The Construction Industry Institute’s (CII) International Project Risk Assessment (IPRA) tool has been developed, successfully used for a variety of heavy industry sector projects, and recently elevated to Best Practice status. However, its current format is inadequate to address the unique challenges of constructing the next generation of nuclear power plants (NPP). To understand and determine the risks associated with NPP projects, the goal of this thesis is to develop tailored risk framework for NPP projects that leverages and modifies the existing IPRA process. The IPRA has 82 elements to assess the risks associated with international construction projects. The modified IPRA adds five major issues (elements) to consider the unique risk factors of typical NPP projects based upon a review of the literature and an evaluation of the performance of previous nuclear-related facilities. The modified IPRA considers the sequence of NPP design that ultimately impacts the risks associated with plant safety and operations. Historically, financial risks have been a major chronic problem with the construction of NPPs. This research suggests that unstable regulations and the lack of design controls and oversight are significant risk issues. This thesis includes a consistency test to initially validate whether the asserted risks exist in actual conditions. Also, an overall risk assessment is performed based on the proposed risk framework for NPP and the list of assessed risk is proposed through a possible scenario. After the assessment, possible mitigation strategies are also provided against the major risks as a part of this thesis. This study reports on the preliminary findings for developing a new risk framework for constructing nuclear power plants. Future research is needed for advanced verification of the proposed elements. Follow-on efforts should include verification and validation of the proposed framework by industry experts and methods to quantify and evaluate the performance and risks associated with the multitude of previous NPP projects.

This study models the HVAC system of a power plant. It involved Computer simulations to study the energy demand by the HVAC system of the power plant as well as the energy demand of the system with modifications on the plant such as the building materials, use of energy efficient lighting, etc. Further studies on the energy demand of the system with the power plant located at different regions of the country were done to understand the effects of climate and locations. It is important to have an understanding of how a plant generating energy uses it for Heating, Ventilating and Air conditioning within the power plant building itself. This study has provided a better understanding of the energy use and how the HVAC system use in the offices and other areas located in the power plant building operates. The study included implementation of energy efficient measures in the choice of building materials for the building. The U.S. Department of Energy (DOE) EnergyPlus program was used to model the HVAC system of the power plant making use of the parameters and modified parameters of the power plant. The results of this study show that the energy demand of the HVAC system of a power plant is significantly affected by the choice of materials for the building. It was found that there is a reduction in the power demand of the HVAC system of the plant by about an average of about 21.7 % at the different the locations. It was also found that this resulted in the amount of energy saved per year of about 87,600 kWh. This gives an average cost savings per year of about $10,512.

A widely-proposed way to retrofit coal-fired power plants with post-combustion CO2 capture (PCC) is to supply all the electricity and heat required to operate the capture equipment from the existing steam cycle (an ‘integrated retrofit’), at the expense of a reduction in site power output. As an alternative, it is possible to add a gas turbine (GT) plant to maintain, or even increase, the net site power output. The GT can be integrated with the capture plant in various ways to supply all or part of the heat and power required for the capture and compression systems. But there is then the issue of how to capture the CO2 emissions from the added GT plant. In this study a novel retrofit configuration is proposed. The exhaust gas of the GT replaces part of the secondary air for the coal boiler and a common capture system is used for both coal- and natural gas-derived CO2. This new ‘GT flue gas windbox retrofit’ is based on the principles of previous hot windbox repowering proposals, with additional modifications to permit operation without extensive coal boiler modifications. To achieve this, the heat recovery steam generator (HRSG) attached to GT is designed to maintain the main steam turbine flow rates and temperatures, to compensate for a necessary reduction in coal feed rates, and this, with the GT output, maintains the net power output of the site A techno-economic analysis of coal plants retrofitted with GT power cycles shows that these ‘power matched’ retrofits can be competitive with integrated retrofits at lower natural gas prices (as is now the case in North America). In particular, the novel GT flue gas windbox retrofit provides a promising alternative for adapting integrated capture retrofits that are initially designed for flexible operation with zero to full (~90%) capture (as at the Boundary Dam 3 unit) for subsequent operation only with full capture. In this case the addition of a GT flue gas windbox retrofit will restore the full power output of the site with full CO2 capture and using the original capture plant. In general, techno-economic analysis shows that the economic performance of GT retrofit options depends on the site power export capacity. If there is no limit on power export then retrofits may advantageously also include an additional steam cycle, to give a combined cycle with the GT, otherwise retrofits with a single pressure HRSG producing process steam only are preferred.

Thesis (M.S.)--Virginia Polytechnic Institute, 1953. / Typewritten. Vita. Bibliography: leaves 90-91. Also available via the Internet.

In recent years the electric power industry has been challenged by a high level of uncertainty and volatility brought on by deregulation and globalization. A power producer must minimize the life cycle cost while meeting stringent safety and regulatory requirements and fulfilling customer demand for high reliability. Therefore, to achieve true system excellence, a more sophisticated system-level decision-making process with a more accurate forecasting support system to manage diverse and often widely dispersed generation units as a single, easily scaled and deployed fleet system in order to fully utilize the critical assets of a power producer has been created as a response. The process takes into account the time horizon for each of the major decision actions taken in a power plant and develops methods for information sharing between them. These decisions are highly interrelated and no optimal operation can be achieved without sharing information in the overall process. The process includes a forecasting system to provide information for planning for uncertainty. A new forecasting method is proposed, which utilizes a synergy of several modeling techniques properly combined at different time-scales of the forecasting objects. It can not only take advantages of the abundant historical data but also take into account the impact of pertinent driving forces from the external business environment to achieve more accurate forecasting results. Then block bootstrap is utilized to measure the bias in the estimate of the expected life cycle cost which will actually be needed to drive the business for a power plant in the long run. Finally, scenario analysis is used to provide a composite picture of future developments for decision making or strategic planning. The decision-making process is applied to a typical power producer chosen to represent challenging customer demand during high-demand periods. The process enhances system excellence by providing more accurate market information, evaluating the impact of external business environment, and considering cross-scale interactions between decision actions. Along with this process, system operation strategies, maintenance schedules, and capacity expansion plans that guide the operation of the power plant are optimally identified, and the total life cycle costs are estimated.

With increasing penetration of intermittent resources such as wind and solar, power system operations are facing much more challenges in cost effective provision of energy balancing and frequency regulation services. Enabled by advances in sensing, control and communication, the concept of Virtual Power Plant (VPP) is proposed as one possible solution which aggregates and firms up spatially distributed resources? net power injection to the system. This thesis proposes a coordinated control and bidding strategy for VPPs to provide energy balancing and grid frequency regulation services in electricity market environment. In this thesis, the VPP consists of two energy conversion assets: a Doubly Fed Induction Generator (DFIG)-based wind farm and a co-located Flywheel Energy Storage System (FESS). The coordination of the VPP is implemented through power electronics?based controllers. A five-bus system test case demonstrates the technical feasibility of VPPs to respond to grid frequency deviation as well as to follow energy dispatch signals. To enable the participation of VPPs in electricity market, this thesis also proposes an optimization based bidding strategy for VPPs in both energy balancing and frequency regulation service markets. The potential economic benefits of this bidding strategy are demonstrated under Denmark wholesale electricity market structure. Four case studies show the economic benefit of coordinating VPPs.

Electricity is directly linked to the economy of a country: when electricity is limited and the price for electricity is very high, the high electricity price will have a negative influence on the economy of the country. Owing to the increasing power shortage in the world, and South Africa in particular, today, the need for reliable and economical electricity has risen drastically. The 100 MWth (40 MWe) PEPER power plant is a possible alternative that will help fight the lack of reliable, clean and affordable electricity in the world today. Owing to the small consumption area of the PEPER power plant, each city, mine and industry, for example, can have its own PEPER power plant in order to ensure reliable, affordable and sustainable electricity. This dissertation presents a case study and the relevant economic model for the PEPER power plant in order to determine whether the PEPER power plant may be considered as a possible electricity source. The production costs of the PEPER are presented in US$/kWh and compared with the industrial and household electricity costs (in US$/kWh) of various countries. This is done in order to determine whether it will be economically feasible to construct a First-of-a-kind (FOAK) or Nth-of-a-kind (NOAK) PEPER power plant in the industrial and household sectors of a selected country. In the economic model of the PEPER plant, the fixed capital investment costs for a FOAK PEPER plant were estimated to be US$367,199,411 and the fixed capital investment costs for a NOAK (eighth) PEPER plant were estimated to be US$238,429,665. The working capital for the first two years of the PEPER plant’s lifetime was estimated to be US$17,228,740. The production cost of the PEPER plant was estimated to be 0.038 US$/kWh. The sensitivity analysis conducted demonstrated that FOAK PEPER plants could be established in countries in which the electricity income is 0.145 US$/kWh or more. NOAK PEPER plants (all the PEPER plants constructed after the eighth PEPER Techno-economic analysis of the 100 MWth PEPER plant Confidential 3 plant is erected) could be established in countries with an electricity income of 0.10 US$/kWh or more. The PEPER plant presented here could be used: 1. as a training tool; 2. to test fuels and materials; 3. to accumulate high temperature nuclear data; and 4. as an electricity source for the industrial and household sectors of selected countries. / Thesis (M.Ing. (Nuclear Engineering))--North-West University, Potchefstroom Campus, 2010