The aim for this study has been to evaluate the integration potential of turbo-machinery into the production processes of biofuels. The focus has been on bio-fuel produced via biomass gasification; mainly methanol and synthetic natural gas. The research has been divided into two parts; gas and steam turbine applications. Steam power generation has a given role within the fuel production process due to the large amounts of excess chemical reaction heat. However, large amounts of the steam produced are used within the production process and is thus not available for power production. Therefore, this study has been focused on lowering the steam demand in the production process, in order to increase the power production. One possibility that has been evaluated is humidification of the gasification agent in order to lower the demand for high quality steam in the gasifier and replace it with waste heat. The results show that the power penalty for the gasification process could be lowered by 18-25%, in the specific cases that have been studied. Another step in the process that requires a significant amount of steam is the CO2-removal. This step can be avoided by adding hydrogen in order to convert all carbon into biofuel. This is also a way to store hydrogen (e.g. from wind energy) together with green carbon. The results imply that a larger amount of sustainable fuels can be produced from the same quantity of biomass. The applications for gas turbines within the biofuel production process are less obvious. There are large differences between the bio-syngas and natural gas in energy content and combustion properties which are technical problems when using high efficient modern gas turbines. This study therefore proposes the integration of a natural gas fired gas turbine; a hybrid plant. The heat from the fuel production and the heat recovery from the gas turbine flue gas are used in a joint steam cycle. Simulations of the hybrid cycle in methanol production have shown good improvements. The total electrical efficiency is increased by 1.4-2.4 percentage points, depending on the fuel mix. The electrical efficiency for the natural gas used in the hybrid plant is 56-58%, which is in the same range as in large-scale combined cycle plants. A bio-methanol plant with a hybrid power cycle is consequently a competitive production route for both biomass and natural gas. / QC 20110128

Energy is one of the biggest costs of production in industries and Small scale industries in Uganda are faced with a big burden due to the high energy costs they incur in their operations. Due to the high costs associated with electricity and fossil fuels, biomass energy continues to supply the bulk (81%) of industrial energy demands. However unsustainable harvesting of tradition biomass fuels (firewood and charcoal) is leading to depletion and causing a hike in prices of this important energy source. This study determined current thermal loads for 4 small scale industries, the costs of the fuels used, possible agro waste replacement options and economic comparisons of gasification using these fuel alternatives. Questionnaires, interviews and quantitative measurements of the various parameters were undertaken to establish current fuel usage and costs. Economic and emission reductions analysis were conducted using RETScreen energy planning tool. Results of indicated that the current combustion and heat transfer devices are very inefficient leading to intensive energy demands. Proposed gasifier systems of the range of 30 kW to 100kW fuel power, would cost between US$ 6,156.35 and US$20,371.20. It was further established that installing gasifiers and incorporating agro wastes in the fuel mix (60%) would greatly reduce expenditure on fuels with pay back periods ranging from 0.4 – 3 years. Risk analysis further showed that fuel costs and operations and maintenance would attract the highest risk to the net present value of each proposed gasifier installation. From these results, it was recommended that gasification coupled with use of agro wastes provides viable cheap alternative for small scale industrial thermal energy needs

No description available.

The integrated gasification combined cycle (IGCC) is the most environmentally friendly coal-fired power generation technology that offers near zero green house gas emissions. This technology has higher thermal efficiency compared to conventional coal-fired power generation plants and uses up to 50% less water. This work involves the optimization of IGCC power plants by applying process integration techniques to maximize the use of energy available within the plant. The basis of this project was the theoretical investigations which showed that optimally designed and operated IGCC plants can achieve overall thermal efficiencies in the regions of 60%. None of the current operating IGCC plants approach this overall thermal efficiency, with the largest capacity plant attaining 47%. A common characteristic in most of these IGCC plants is that an appreciable amount of energy available within the system is lost to the environment through cold utility, and through plant irreversibility to a smaller extent. This work focuses on the recovery of energy, that is traditionally lost as cold utility, through application of proven process integration techniques. The methodology developed comprises of two primary energy optimization techniques, i.e. pinch analysis and the contact economizer system. The idea behind using pinch analysis was to target for the maximum steam flowrate, which will in turn improve the power output of the steam turbine. An increase in the steam turbine power output should result in an increase in the overall thermal efficiency of the plant. The contact economizer system is responsible for the recovery of low potential heat from the gas turbine exhaust en route to the stack to heat up the boiler feed water (BFW). It was proven in this work that a higher BFW enthalpy results in a higher overall efficiency of the plant. A case study on the Elcogas plant illustrated that the developed method is capable of increasing the gross efficiency from 47% to 55%. This increase in efficiency, however, comes at an expense of increased heat exchange area required to exchange the extra heat that was not utilized in the preliminary design. / Dissertation (MEng)--University of Pretoria, 2011. / Chemical Engineering / unrestricted

No description available.

No description available.

The following chapters deal with the chemistry, catalytic poisoning, newer catalyst technologies, and possible future solutions to increase the efficiency of creating high-value products by thermochemically converting gasified biomass (producer gas). Chapter 1 puts emphasis on multifunctional catalysts containing transition metals that are used for renewable fuel production. High-value products such as gasoline-range hydrocarbons, dimethyl ether (DME), aldehydes, isobutane, isobutene and other olefins can be produced with gasified biomass due to the gas containing syngas (H2 + CO). The chemistry and production of these chemicals is discussed in the review. Chapter 2 describes the reactor design of a bench scale system and results after using a Mo/HZSM- 5 catalyst for aromatic hydrocarbon creation. This chapter also discusses issues that came with trying to control the temperature without any reactor intercooling. Chapter 3 shows the feasibility of using a particular multifunctional catalyst with a lab scale system and also shows the importance of certain process variables including temperature, space velocity, gas ratios, and pressure. The subject of the importance of the cleanliness of the producer gas is also discussed so that maximum high-value product yield can be achieved with the greatest efficiency. Chapter 4 discusses the implementation of a bench scale and pilot scale reactor design (both with intercooling) and the results of scale-up when using the catalyst mentioned in Chapter 3. Chapter 5 involves the modelling of an industrialized system with Aspen Plus. The economics of industrial plants to produce hydrocarbons from coal or wood feedstocks at scales of 5, 50 and 5000 tons per day were modeled using CAPCOST.

Biomass-derived hydrocarbons that include gasoline, diesel, and jet fuel will help replace finite fossil fuel hydrocarbons of the same range. This study showed that temperature could be controlled in a scaled-up reactor system using three types of syngas. The CO conversion, selectivity and amount of product created from each type of syngas were examined. Clean syngas composed of 40% H2, 20% CO, 12% CO2, 2% CH4, and 26 % N2 was used to test ideal stoichiometric molar values. Clean syngas composed of 19% H2, 20% CO, 12% CO2, 2% CH4, and 47 % N2 was used to test an ideal contaminateree synthesis gas situation to mimic our particular downdraft gasifier. Gasifier wood syngas composed of 19% H2, 20% CO, 12% CO2, 2% CH4, 46 % N2, and 1% O2 was used in this study to determine the feasibility of using gasified biomass syngas to produce gasolinerange hydrocarbons.

Since bio-gasification is a potentially more efficient way to utilize bio-energy, the economic feasibility becomes one of the greatest issues when we apply this new technology. Evaluation of economic feasibility of a bio-gasification facility needs understanding of its production unit cost under different capacities and different working shift modes. The objectives of this study were to evaluate the unit cost of bio-syngas and biouel products at different capacities by using economic modeling method. Result showed that economic feasibility of a power facility was significantly affected by its production capacity and operating mode (one shift, two shifts, or three shifts mode). Economic feasibility could be improved by increasing production capacity or by changing operating mode to two or three shifts from one shift. The economic evaluation model and cost analysis software developed in this study could be a good tool for economic analysis of bio-syngasand biouel products from biomass gasification.

No description available.