Influence of the composition of natural gas-hydrogen blends (HCNG) on performance an CO2 emissions of a spark ignition engine

Addition of hydrogen to natural gas could be a short-term alternative to nowadays fossil fuels as the emissions of greenhouse gases may be reduced. The aim of this study is to evaluate the performance and emissions of a park ignition engine fuelled with pure natural gas, pure hydrogen and different blends of hydrogen and natural gas (HCNG). The increase of the hydrogen fraction leads to variations in the cylinder pressure and CO2 emissions. In this work, a combustion model based on thermodynamic equations is used considering separated zones for the burned and unburned gases. The results show that the maximum cylinder pressure gets higher as the fraction of hydrogen in the blend increases. The presence of hydrogen in the blend leads to a drecrease in the CO2 emissions. Due to hydrogen properties, leaner fuel-air mixtures can be used along with the appropiate spark timing, leading to an engine emissions improvement without a performance worsening.

Life cycle assessment of concentrated solar power (CSP) and the influence of hybridising with natural gas

Purpose Concentrating Solar Power (CSP) plants based on parabolic troughs utilize auxiliary fuels (usually natural gas) to facilitate start-up operations, avoid freezing of HTF and increase power output. This practice has a significant effect on the environmental performance of the technology. The aim of this paper is to quantify the sustainability of CSP and to analyse how this is affected by hybridisation with different natural gas (NG) inputs. Methods A complete Life Cycle (LC) inventory was gathered for a commercial wet-cooled 50 MWe CSP plant based on parabolic troughs. A sensitivity analysis was conducted to evaluate the environmental performance of the plant operating with different NG inputs (between 0 and 35% of gross electricity generation). ReCiPe Europe (H) was used as LCA methodology. CML 2 baseline 2000 World and ReCiPe Europe E were used for comparative purposes. Cumulative Energy Demands (CED) and Energy Payback Times (EPT) were also determined for each scenario. Results and discussion Operation of CSP using solar energy only produced the following environmental profile: climate change 26.6 kg CO2 eq/KWh, human toxicity 13.1 kg 1,4-DB eq/KWh, marine ecotoxicity 276 g 1,4-DB eq/KWh, natural land transformation 0.005 m2/KWh, eutrophication 10.1 g P eq/KWh, acidification 166 g SO2 eq/KWh. Most of these impacts are associated with extraction of raw materials and manufacturing of plant components. The utilization NG transformed the environmental profile of the technology, placing increasing weight on impacts related to its operation and maintenance. Significantly higher impacts were observed on categories like climate change (311 kg CO2 eq/MWh when using 35 % NG), natural land transformation, terrestrial acidification and fossil depletion. Despite its fossil nature, the use of NG had a beneficial effect on other impact categories (human and marine toxicity, freshwater eutrophication and natural land transformation) due to the higher electricity output achieved. The overall environmental performance of CSP significantly deteriorated with the use of NG (single score 3.52 pt in solar only operation compared to 36.1 pt when using 35 % NG). Other sustainability parameters like EPT and CED also increased substantially as a result of higher NG inputs. Quasilinear second-degree polynomial relationships were calculated between various environmental performance parameters and NG contributions. Conclusions Energy input from auxiliary NG determines the environmental profile of the CSP plant. Aggregated analysis shows a deleterious effect on the overall environmental performance of the technology as a result of NG utilization. This is due primarily to higher impacts on environmental categories like climate change, natural land transformation, fossil fuel depletion and terrestrial acidification. NG may be used in a more sustainable and cost-effective manner in combined cycle power plants, which achieve higher energy conversion efficiencies.

Hybridizing concentrated solar power (CSP) with biogas and biomethane as an alternative to natural gas: Analysis of environmental performance using LCA

Concentrating Solar Power (CSP) plants typically incorporate one or various auxiliary boilers operating in parallel to the solar field to facilitate start up operations, provide system stability, avoid freezing of heat transfer fluid (HTF) and increase generation capacity. The environmental performance of these plants is highly influenced by the energy input and the type of auxiliary fuel, which in most cases is natural gas (NG). Replacing the NG with biogas or biomethane (BM) in commercial CSP installations is being considered as a means to produce electricity that is fully renewable and free from fossil inputs. Despite their renewable nature, the use of these biofuels also generates environmental impacts that need to be adequately identified and quantified. This paper investigates the environmental performance of a commercial wet-cooled parabolic trough 50 MWe CSP plant in Spain operating according to two strategies: solar-only, with minimum technically viable energy non-solar contribution; and hybrid operation, where 12 % of the electricity derives from auxiliary fuels (as permitted by Spanish legislation). The analysis was based on standard Life Cycle Assessment (LCA) methodology (ISO 14040-14040). The technical viability and the environmental profile of operating the CSP plant with different auxiliary fuels was evaluated, including: NG; biogas from an adjacent plant; and BM withdrawn from the gas network. The effect of using different substrates (biowaste, sewage sludge, grass and a mix of biowaste with animal manure) for the production of the biofuels was also investigated. The results showed that NG is responsible for most of the environmental damage associated with the operation of the plant in hybrid mode. Replacing NG with biogas resulted in a significant improvement of the environmental performance of the installation, primarily due to reduced impact in the following categories: natural land transformation, depletion of fossil resources, and climate change. However, despite the renewable nature of the biofuels, other environmental categories like human toxicity, eutrophication, acidification and marine ecotoxicity scored higher when using biogas and BM.

Dimensionamiento del proceso de licuación de una planta de gas natural Offshore

Este proyecto consiste en el dimensionamiento del proceso de licuación de una planta offshore para la producción de gas natural licuado, usando únicamente N2 como refrigerante, evitando de este modo riesgos potenciales que podrían surgir con el uso de refrigerantes mixtos compuestos de hidrocarburos. El proceso ha sido diseñado para acomodar 35,23 kg/s (aproximadamente un millón de toneladas por año) de gas natural seco, sin separación de gases licuados de petróleo (GLP) y ajustarlo dentro de los parámetros requeridos en las especificaciones del proceso. Para proceder al dimensionamiento del proceso de licuación de gas natural de la planta se ha empleado el programa Aspen Plus. Los sistemas floating production, storage and offloading para licuar el gas natural (LNG-FPSO), es una nueva unidad conceptual y un modo realista y efectivo para la explotación, recuperación, almacenamiento, transporte y agotamiento de los campos marginales de gas y las fuentes de gas asociadas offshore. En el proyecto se detalla el proceso, equipos necesarios y costes estimados, potencia aproximada requerida y un breve análisis económico. ABSTRACT This project consist of the dimensioning of a liquefaction process in an offshore plant to produce liquefied natural, using only N2 as refrigerant in the cooling cycles to avoid potential hazards of mixed hydrocarbon refrigerants. The process was designed to accommodate 35.23 kg/s (roughly 1 MTPA) of raw natural gas feed without separation of LPG, and fits within all parameters required in the process specifications. The plant has been designed with the computer tool Aspen Plus. The floating production, storage and offloading system for liquefied natural gas (LNGFPSO), is a new conceptual unit and an effective and realistic way for exploitation, recovery, storage, transportation and end-use applications of marginal gas fields and offshore associated-gas resources. The following report details the process, equipment needs and estimated costs, approximated power requirements, and a brief economic analysis.

Recuperación secundaria en campos de petróleo y su conversión en almacenamientos subterráneos de gas natural

El objetivo de este proyecto es estudiar la recuperación secundaria de petróleo de la capa sureste Ayoluengo del campo Ayoluengo, Burgos (España), y su conversión en un almacenamiento subterráneo de gas. La capa Ayoluengo se ha considerado como una capa inclinada de 60 km por 10 km de superficie por 30 m de espesor en el que se han perforado 20 pozos, y en donde la recuperación primaria ha sido de un 19%. Se ha realizado el ajuste histórico de la recuperación primaria de gas, petróleo y agua de la capa desde el año 1965 al 2011. La conversión a almacenamiento subterráneo de gas se ha realizado mediante ciclos de inyección de gas, de marzo a octubre, y extracción de gas, de noviembre a febrero, de forma que se incrementa la presión del campo hasta alcanzar la presión inicial. El gas se ha inyectado y extraído por 5 pozos situados en la zona superior de la capa. Al mismo tiempo, se ha realizado una recuperación secundaria debido a la inyección de gas natural de 20 años de duración en donde la producción de petróleo se realiza por 14 pozos situados en la parte inferior de la capa. Para proceder a la simulación del ajuste histórico, conversión en almacenamiento y recuperación secundaria se utilizó el simulador Eclipse100. Los resultados obtenidos fueron una recuperación secundaria de petróleo de un 9% más comparada con la primaria. En cuanto al almacenamiento de gas natural, se alcanzó la presión inicial consiguiendo un gas útil de 300 Mm3 y un gas colchón de 217,3 Mm3. ABSTRACT The aim of this project is to study the secondary recovery of oil from the southeast Ayoluengo layer at the oil field Ayoluengo, Burgos (Spain), and its conversion into an underground gas storage. The Ayoluengo layer is an inclined layer of 60 km by 10km of area by 30 m gross and with 20 wells, which its primary recovery is of 19%. The history matching of the production of oil, gas and water has been carried out from the year 1965 until 2011. The conversion into an underground gas storage has been done in cycles of gas injection from March to October, and gas extraction from November to February, so that the reservoir pressure increases until it gets to the initial pressure. The gas has been injected and extracted through five well situated in the top part of the layer. At the same time, the secondary recovery has occurred due to de injection of natural gas during 20 years where the production of oil has been done through 14 wells situated in the lowest part of the layer. To proceed to the simulation of the history match, the conversion into an underground gas storage and its secondary recovery, the simulator used was Eclipse100. The results were a secondary recovery of oil of 9% more, compared to the primary recovery and concerning the underground gas storage, the initial reservoir pressure was achieved with a working gas of 300 Mm3 and a cushion gas of 217,3 Mm3.

Criterios de selección de una estructura favorable para un almacenamiento de gas natural : Aplicación a escala de cuenca en la Península Ibérica

RESUMEN Este proyecto ha tenido por objetivo el estudio de la viabilidad de instalar un nuevo almacenamiento subterráneo de gas natural en España. Dentro de las diferentes posibilidades para emplazar el almacenamiento de gas natural se escogió el domo salino por ser la estructura geológica más favorable desde el punto de vista técnico y económico. Una vez escogido el domo salino, el estudio se centró en localizar una ubicación lo más favorable posible siendo el domo salino de Salinas de Añana el elegido. Una vez elegido el domo se procedió al estudio de la viabilidad técnica de la instalación; para ello se utilizaron estudios geológicos, gavimétricos y sondeos. Tras estos estudios se concluyó que en el domo salino de Salinas de Añana es posible la instalación de un almacenamiento subterráneo de gas natural y se procedió a la caracterización del almacenamiento. ABSTRACT This project has considered of installing a new underground natural gas storage in Spain. Among the different possibilities to place a natural gas storage, the salt dome was chosen because it was the geological strucutrure where the project was easier and more interesting economically. After that the study focused on looking for the location as favorable as possible. The best place was the salt dome of Salinas de Añana. Before the salt dome of Salinas de Añana was chosen this project tried to know if the setting-up of a natural gas storage is technical feasibility. For that were used geological studies, gravity studies and drillings. These studies concluded that is possible the setting-up and the study tried to describe technically this storage.

Analysis of the Behaviour of Biofuel-Fired Gas Turbine Power Plants

The utilisation of biofuels in gas turbines is a promising alternative to fossil fuels for power generation. It would lead to significant reduction of CO2 emissions using an existing combustion technology, although significant changes seem to be needed and further technological development is necessary. The goal of this work is to perform energy and exergy analyses of the behaviour of gas turbines fired with biogas, ethanol and synthesis gas (bio-syngas), compared with natural gas. The global energy transformation process (i.e. from biomass to electricity) has also been studied. Furthermore, the potential reduction of CO2 emissions attained by the use of biofuels has been determined, considering the restrictions regarding biomass availability. Two different simulation tools have been used to accomplish the aims of this work. The results suggest a high interest and the technical viability of the use of Biomass Integrated Gasification Combined Cycle (BIGCC) systems for large scale power generation.

Gestión del boil off gas en la planta de regasificación de Cartagena

Este proyecto trata sobre la gestión del boil-off gas, o BOG (vapor de gas natural que se produce en las instalaciones de gas natural licuado de las plantas de regasificación), generado en la planta de regasificación de Gas Natural Licuado de Cartagena, tanto en las situaciones en las que se opera por debajo del mínimo técnico, como en las cargas y descargas de buques, en las cuales se ha de gestionar una cantidad del boil-off adicional. Para recuperar el boil-off, las plantas cuentan con un relicuador (intercambiador de calor) en el que el BOG es relicuado por el GNL que se envía a los vaporizadores para ser regasificado y emitido a la red. De forma complementaria cuentan también con una antorcha/venteo donde se quema el exceso de boil-off que no puede ser tratado por el relicuador. Se procede a un análisis de la situación actual, y de cómo la baja demanda de regasificación dificulta la gestión del boil-off. Se simula el proceso de relicuación actual en distintas situaciones de operación. Ante la situación de baja demanda, ha aumentado considerablemente el número de días en los que las plantas españolas en general, y la planta de Cartagena en particular, operan por debajo del mínimo técnico, que es el nivel de producción mínimo para recuperar todo el boil-off generado en cualquier situación de operación al tiempo que mantiene en frío todas las instalaciones, y garantiza el 100% de disponibilidad inmediata del resto de los equipos en condiciones de seguridad de funcionamiento estable. Esta situación supone inconvenientes tanto operativos como medioambientales y acarrea mayores costes económicos, a los cuales da solución el presente proyecto, decidiendo qué alternativa técnica es la más adecuada y definiéndola. Abstract This project is about the management of the boil-off gas (BOG), natural vapour gas that is produced in liquefied natural gas (LNG) regasification plants. Specifically, the study is focused on the LNG regasification plant located in Cartagena, when it operates both below the technical minimum level of regasification and in the loading/unloading of LNG carriers, situations when it is needed to handle additional BOG. In order to make the most of BOG, the plants have a re-condenser (heat exchanger). Here, the BOG is re-liquefied by the LNG that is submitted to the vaporizers and delivered to the grid. The plants also have a flare/vent where the excess of BOG that cannot be treated by the re-condenser is burned. An analysis of the current situation of the demand is performed, evaluating how low markets demand for regasification difficult the BOG management. Besides, it is simulated the current re-liquefaction operating in different environments. Due to the reduction of the demand for natural gas, the periods when Spanish LNG regasification plants (and particularly the factory of Cartagena) are operating below the technical minimum level of regasification are more usual. This level is the minimum production to recover all the BOG generated in any operating situation while maintaining cold all facilities, fully guaranteeing the immediate availability from other equipment in a safely and stable operation. This situation carries both operational and environmental drawbacks, and leads to higher economic costs. This project aims to solve this problem, presenting several technical solutions and deciding which is the most appropriate.

Evaluación ambiental de las tecnologías de recuperación de gas en formaciones no convencionales

Este proyecto pretende ofrecer una visión general de una de las tecnologías más actuales de recuperación de gas en formaciones no convencionales: fracturación hidráulica o “fracking”. El proyecto está motivado por la necesidad de responder a diferentes cuestiones sobre los efectos ambientales, sociales y en la salud humana derivados de la utilización de esa tecnología. Ofrece, además, una descripción del proceso y utilización de la tecnología haciendo especial mención de los riesgos inherentes de su uso, aunque también se intenta establecer una vía de aceptación para su desarrollo cuyo fin último, a parte de los beneficios económicos de quienes la usan, es el de posibilitar la transición hacia el uso de unos recursos (energías fósiles de extracción no convencional) que requieren de dichas técnicas para mantener, a lo largo del tiempo, el suministro de una energía que se supone más respetuosa con el medio ambiente: el gas natural. En primer lugar se expone, a modo introductorio, la necesidad de utilización de nuevas técnicas de estimulación de pozos y su utilización para satisfacer las necesidades energéticas mundiales en los próximos años. A continuación se hace una revisión del marco regulatorio aplicable al gas no convencional. Seguidamente, se hace una descripción de los recursos y fuentes no convencionales de gas y la descripción del proceso de fracturación hidráulica. Se analizan los incidentes relacionados con su desarrollo y las posibilidades y mecanismos que pueden adoptarse para reducirlos. Finalmente, se proponen vías alternativas basadas en las mejores técnicas aplicables al uso de la tecnología, cuya finalidad sea la mayor consideración ambiental posible y el menor riesgo posible en la salud de las personas. ABSTRACT This project aims to provide an overview of the latest technologies in gas recovery unconventional formations: hydraulic fracturing or "fracking". The project is motivated by the need to respond to various questions on the environmental, social and human health arising from the use of this technology. It also offers a description of the process and use of technology with special mention of the inherent risks of their use, but also tries to establish a path of acceptance for development whose ultimate goal, apart from the economic benefits of those who use is of enabling the transition to the use of certain resources (fossil energy extraction unconventional) which require such techniques to maintain, over time, of an energy supply which is more environmentally friendly: natural gas. First discussed the need to use new well stimulation techniques and their use to meet the world's energy needs in the coming years. Below is a review of the regulatory framework applicable to unconventional gas. Next, there is a description of resources and unconventional sources of gas, and the description of the process of hydraulic fracturing. We analyze the incidents related to its development and the possibilities and mechanisms that can be taken to reduce them. Finally, we suggest alternative routes based on the best techniques applicable to the use of technology, aiming at the highest possible environmental consideration and the least possible risk to the health of people.

Identificación de los riesgos ambientales y sanitarios de la producción de gas mediante fracturación hidráulica y bases para una propuesta metodológica de vulnerabilidad de las aguas subterráneas

Hasta ahora, la gran mayoría de los recursos explotados de gas natural procedían de acumulaciones convencionales de gas aislado y de gas asociado y disuelto en el petróleo. Sin embargo, el gas natural se encuentra también en yacimientos que, debido a su baja porosidad y permeabilidad, tienen unas características que hacen que hasta muy recientemente no hayan sido económicamente rentables y que sólo puedan ser explotados mediante técnicas no convencionales, dando lugar al denominado gas no convencional. Las técnicas utilizadas para su extracción son la fracturación hidráulica o “fracking” y la perforación horizontal. Entre los diversos tipos de gas no convencional, es de prever que el gas de pizarra sea el que sufra mayor desarrollo a medio plazo en nuestro país, por lo que se están generando grandes debates, debido al riesgo de contaminación de las aguas superficiales y subterráneas del entorno, provocados por la elevada cantidad de agua utilizada, los aditivos empleados, los fluidos de retorno, por la alteración del medio físico, así como por la dificultad de monitorización de estos procesos. En este proyecto se identifican los riesgos ambientales y sanitarios asociados a la extracción de gas no convencional. El trabajo se basa principalmente en experiencias ocurridas en países donde el fracking se ha convertido en una práctica habitual. Se trata además de establecer las bases necesarias para la estimación de la vulnerabilidad de los acuíferos frente a la contaminación inducida por la fracturación hidráulica. Abstract Until now, most of the natural gas resources exploited were from isolated conventional gas accumulations and associated and dissolved gas in oil. However, the natural gas is also in reservoirs that, due to their low porosity and permeability, have characteristics that make until recently not been economically profitable and can be exploited only by unconventional techniques, leading to the so called unconventional gas. The techniques used for extraction are hydraulic fracturing or "fracking" and horizontal drilling. Among the various types of unconventional gas, it is expected that shale gas is the suffering greater medium-term development in our country, so it is generating much debate, due to the risks of contamination in surface waters and subterranean environment, caused by the high amount of water used, the additives used, the return fluid, by altering the physical environment, and the difficulty of monitoring these processes. In this project identifies the environmental and health risks associated with unconventional gas extraction. The work is mainly based on experiences that occurred in countries where fracking has become a common practice. This is for establish the necessary basis for estimating the vulnerability of aquifers from contamination induced by hydraulic fracturing.

Optimización del coste de aprovisionamiento de gas en el mercado mayorista español para una comercializadora

Los precios de compra de gas natural en el mercado mayorista español son los más altos de toda Europa. Este escenario provoca que haya que buscar alternativas para minimizar los costes de aprovisionamiento para una comercializadora de gas. En este proyecto se analizan distintas oportunidades de compra de gas en los mercados europeos y su importación al sistema gasista español para el suministro final a clientes, con el fin de optimizar los costes del gas natural para una comercializadora. En la búsqueda de nuevas oportunidades se incluye también un análisis del impacto económico en el mercado, de la producción de “shale gas” en España a medio - largo plazo. ABSTRACT The gas prices in the Spanish gas market are the highest in Europe. This scenario leads the Spanish gas trading companies to look for alternatives to minimize gas supply costs. In this project it is analyzed different opportunities of gas supply in the European markets and the gas import to the Spanish gas system, in order to optimize the costs of the natural gas for a gas trading company. Along with this, it is also studied, the economic impact of the “shale gas” production in Spain in a medium - long term on the Spanish gas market

CO2 emissions from a spark ignition engine operatin on natural-hydrogen blends (HCNG)

The addition of hydrogen to natural gas could be a short-term alternative to today’s fossil fuels, as greenhouse gas emissions may be reduced. The aim of this study is to evaluate the emissions and performance of a spark ignition engine fuelled by pure natural gas, pure hydrogen, and different blends of hydrogen and natural gas (HCNG). Increasing the hydrogen fraction leads to variations in cylinder pressure and CO2 emissions. In this study, a combustion model based on thermodynamic equations is used, considering separate zones for burned and unburned gases. The results show that the maximum cylinder pressure rises as the fraction of hydrogen in the blend increases. The presence of hydrogen in the blend leads to a decrease in CO2 emissions. Due to the properties of hydrogen, leaner fuel–air mixtures can be used along with the appropriate spark timing, leading to an improvement in engine emissions with no loss of performance.

An Empirical Analysis of the Spanish Gas Price Structure

We can say without hesitation that in energy markets a throughout data analysis is crucial when designing sophisticated models that are able to capture most of the critical market drivers. In this study we will attempt to investigate into Spanish natural gas prices structure to improve understanding of the role they play in the determination of electricity prices and decide in the future about price modelling aspects. To further understand the potential for modelling, this study will focus on the nature and characteristics of the different gas price data available. The fact that the existing gas market in Spain does not incorporate enough liquidity of trade makes it even more critical to analyze in detail available gas price data information that in the end will provide relevant information to understand how electricity prices are affected by natural gas markets. In this sense representative Spanish gas prices are typically difficult to explore given the fact that there is not a transparent gas market yet and all the gas imported in the country is negotiated and purchased by private companies at confidential terms.

Use of alternative fuels obtained from renewable sources in brayton cycles

Analysis and simulation of the behaviour of gas turbines for power generation using different nonconventional fuels obtained from different renewable sources are presented. Three biomass-tobiofuel processes are considered: anaerobic digestion of biomass (biogas), biomass gasification (synthesis gas) and alcoholic fermentation of biomass and dehydration (bioethanol), each of them with two different biomass substrates (energy crops and municipal solid waste) as input. The gas turbine behaviour in a Brayton cycle is simulated both in an isolated operation and in combined cycle. The differences in gas turbine performance when fired with the considered biofuels compared to natural gas are studied from different points of view related with the current complex energetic context: energetic and exergetic efficiency of the simple/combined cycle and CO2 emissions. Two different tools have been used for the simulations, each one with a different approach: while PATITUG (own software) analyses the behaviour of a generic gas turbine allowing a total variability of parameters, GT-PRO (commercial software) is more rigid, albeit more precise in the prediction of real gas turbine behaviour. Different potentially interesting configurations and its thermodynamic parameters have been simulated in order to obtain the optimal range for all of them and its variation for each fuel.

Optimización de la metodología de contratación de carbones térmicos con destino a la generación eléctrica

En los últimos quince años se ha producido una liberalización de los mercados eléctricos en los distintos países de ámbito occidental que ha ido acompañado de un incremento por la preocupación por la incidencia de las distintas tecnologías de generación en el entorno medioambiental. Ello se ha traducido en la aparición de un marco regulatorio más restrictivo sobre las tecnologías de generación fósiles, con mayor incidencia en las derivadas de productos petrolíferos y carbón. A nivel mundial han ido apareciendo cambios normativos relativos a las emisiones de distintos elementos contaminantes (CO2, SO2, NOx…), que hacen que en particular las centrales térmicas de carbón vean muy afectadas su rentabilidad y funcionamiento. Esta situación ha supuesto que la tecnología de generación eléctrica con carbón haya avanzado considerablemente en los últimos años (calderas supercríticas, sistemas de desulfuración, gasificación del carbón…). No obstante, el desarrollo de la generación con energías renovables, la generación con gas mediante centrales de ciclo combinado y la opinión social relativa a la generación con carbón, principalmente en Europa, suponen un serio obstáculo a la generación con carbón. Por consiguiente, se hace necesario buscar vías para optimizar la competitividad de las centrales de carbón y el camino más razonable es mejorar el margen esperado de estas plantas y en particular el coste de adquisición del carbón. Ello se hace aún más importante por el hecho de existir numerosas centrales de carbón y un elevado número de nuevos proyectos constructivos de centrales de carbón en países asiáticos. Por consiguiente, el objeto de la presente tesis doctoral se centra en definir una metodología para optimizar la compra de carbón, desde el punto de vista económico y técnico, con destino a su consumo en una central térmica, con ello reducir el coste del carbón consumido y mejorar su competitividad. También se enfoca a determinar que herramientas pueden ser utilizadas para optimizar la gestión del carbón después de su compra y con ello abrir la posibilidad de obtener márgenes adicionales para dicho carbón. De acuerdo con este objetivo, el autor de la presente Tesis Doctoral realiza tres aportaciones novedosas en el ámbito de la contratación de carbón térmico y su optimización posterior: - Evaluación de carbones para su adquisición considerando el efecto de la calidad del carbón en el coste de generación asociado a cada carbón ofertado. - Creación, desarrollo, implantación y utilización de una potente herramienta de planificación de Combustibles. Esta herramienta, está diseñada con el objeto de determinar la solución económica óptima de aprovisionamientos, consumos y niveles de existencias para un parque de generación con centrales de carbón y fuelóleo. - La extensión de una metodología contractual habitual en el mercado spot de Gas Natural Licuado, a la contratación spot de Carbón de Importación. Esta se basa en el desarrollo de Acuerdos Marcos de Compra/Venta de carbón, que por su flexibilidad permitan obtener resultados económicos adicionales después de la compra de un carbón. Abstract In the last fifteen years, a liberalization of the electrical markets has occurred in the western countries. This process has been accompanied by an increasing concern of the impact of the different generation technologies towards the environment. This has motivated a regulated framework restricting the use of fossil fuels, impacting a great deal in coal and oil based products. Worldwide, new legal changes have been arising related to the emissions of the different pollutants (CO2, SO2, NOx…). These changes have had a deep impact in the feasibility, profit and running of coal fired power plants. This situation has motivated the coal electrical generation technologies to move forward in an important way in the last few years (supercritical furnaces, desulphuration plants, coal gasification…). Nevertheless, the development of the renewable generation, the gas combined cycle generation and the social opinion related to the coal electrical generation, mainly in Europe, have created a serious obstacle to the generation of electricity by coal. Therefore it is necessary to look for new paths in order to optimize the competitiveness of the coal fired power plants and the most reasonable way is to improve the expected margin of these plants and particularly the coal purchase cost. All of the above needs to be taken into context with the large number of existing coal fired power plants and an important number of new projects in Asian countries. Therefore, the goal of the current doctoral dissertation is focused to define a methodology to be considered in order to optimize the coal purchase, from an economical and a technical point of view. This coal, destined for power plant consumption, permits the reduction of consumption coal cost and improves the plant’s competitiveness. This document is also focused to define what tools we can use to optimize the coal management after deal closing and therefore open the possibility to get further margins. According to this goal, the author of this doctoral dissertation provides three important new ideas in the ambit of contracting steam coal and the posterior optimization: - Evaluation of coal purchases, considering the effect of coal quality on the cost of generation associated with each type of coal offered. - The creation, development, deployment and use of a strong planning tool of fuels. This tool is designed for the purpose of determining the optimal economic solution of fuel supply, consumption and stock levels for a power generation portfolio using coal and fuel oil fired power plants. - The application of a common contractual methodology in the spot market of Liquid Natural Gas, for the contracting spot imported coal. This is based on the development of Framework Agreements for the Purchasing / Sale of coal, which because of its flexibility allows for the gain of additional financial results after the purchase of coal.