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Abstract Global warming and CO2 emissions have been a great concern and serious threat to human beings. Even though the problem is clear and well-known, there are still debates among the scientists in the causes of such changes. On the other hand, numbers of studies indicated that there is a good relationship between global warming and CO2 emissions. The extensive use of non-renewable energy resources such as oil is one of the main factors to cause these changes. After discovering oil around 1960, the United Arab Emirates (UAE) face very fast economical development accompanied with population growth. These bring tremendous demand on energy in different sectors such as industry, commercial and residential. Oil was a main source to generate energy to respond to these great demands. This study presents the relationship between CO2 emission and temperature change in the UAE with respect to the global warming. The CO2 emissions of UAE in last 48 years are averaged about 33.6 metric tons per capita. This clearly shows that an average of UAE's CO2 emission in last 48 years is about 8 times higher than the world average CO2 emissions of 4.1 metric tons per capita. In the UAE, the mean highest and the lowest temperature were recorded 28.7 (in 1998) and 26.5 (in 1992) C respectively during the last 18 years. The mean rainfall data exhibit more scattering than the mean temperature data. During the last 10 years, even though the mean average temperature data indicates stabilization of around 28.4C, the mean average rainfall data shows considerable decrement from 12.8 to 4.61 mm compare to the previous years. If this trend continues for decades, the area will have less and less rain and will be hotter. Accordingly, it is fact that increases in CO2 concentration in the atmosphere causes temperature increase and contributes in global warming.
- Government (1.00)
- Energy > Renewable (1.00)
Abstract In this presentation, the author's goal is to help corporate decision-makers address a materiality gap by providing a practical methodology on how to estimate carbon related costs and benefits in financial terms using a registry-grade GHG inventory as its foundation. Companies are faced with significant analytical and operational challenges and uncertainties when planning long-term growth strategies and capital investments. One important aspect that is overlooked in traditional business decision processes is trying to account for potential carbon related risks and opportunities. The proposed framework allows a company to develop a top-down perspective through the lens of a Corporate Carbon Impact Statement supported by a carbon-conscious capital budgeting approach.First, this presentation will discuss current climate policy and market drivers to gain an understanding of current and future requirements. Second, current best practices in GHG emissions accounting will be discussed, including major challenges faced (such as defining organizational boundaries and selecting a consolidation methodology). Third, the author will introduce the concept of a "Corporate Carbon Impact Statement" to help companies convert their GHG data into financial estimates of potential assets and liabilities. Fourth, practical measures will be discussed, such as full implementation of internal risk governance and capital budgeting processes that can be utilized to integrate the impacts of GHGs into company's decision-making and offer financial management tools and techniques to assist that decision-making. At the end, the author will present a carbon risk assessment framework to support global organizations faced with significant assets and liabilities posed by climate regulations and carbon markets.
- Law > Environmental Law (1.00)
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy (1.00)
- Banking & Finance > Trading (1.00)
Abstract CO2 injection has been used in the oil industry as an effective technique for enhanced recovery of light to medium oils. However, its utilization for heavy oil recovery has not gained enough attention because of the immiscible nature of heavy oil and CO2. Due to high solubility of CO2 in both water and oil, the overall heavy oil recovery from waterflooding can be improved by adding CO2 to the injected water. CO2 injection for the geological storage in heavy oil reservoirs can also reduce its emissions and contribute towards development of clean fossil fuel production and climate change mitigation. This paper presents the simulation study of injecting CO2 to improve the efficiency of heavy oil waterflooding and evaluate the potential of CO2 geological storage as a part of this process. In this study, a compositional simulation model was built based on a previous experimental work and validated by comparing the simulation results with experimental data. The sensitivity analysis was run on the validated model to examine the effects of different parameters including injection scheme (separate slugs of pure CO2/carbonated water and continuous carbonated waterflooding), injection pressure, and CO2 slug size on the heavy oil recovery and CO2 storage capacity. This study shows that CO2 can enhance the efficiency of heavy oil waterfloofing and a considerable amount of CO2 can be stored inside the porous media. Additional recovery factors up to 28% OOIP were achieved by injecting CO2 in combination with water while CO2 storage capacity of 22.5?93.6% of the injected CO2 was obtained. It was found that depending on CO2 injection pressure, different injection schemes can lead to variant accumulative heavy oil productions and CO2 storage capacities. In general, continuous carbonated waterflooding resulted in a higher amount of CO2 to be injected and stored inside the simulation model. In addition, it was observed that increase in the CO2 injection pressure enhances the heavy oil recovery and subsequently causes more CO2 to be stored. Moreover, injecting a larger CO2 slug size did not considerably change the ultimate accumulative heavy oil production and CO2 storage capacity. Introduction Western Canada has tremendous heavy oil deposits which are mainly located in east-central Alberta and extended into western Saskatchewan1. These heavy oil deposits are amongst the largest in the world with the estimated OOIP of more than 5201 million m3.2 Effective and economical recovery of such heavy oil deposits has gained considerable attention due to increase in demand for hydrocarbon fuels and decline in production from conventional light and medium oil resources. The primary recovery factor from heavy oil reservoirs is typically as low as 6?8% of the original-oil-in-place (OOIP) which is mainly because of the extremely high viscosities and almost immobile conditions of the heavy oils under the actual reservoir conditions3,4. Waterflooding as a secondary recovery method is often employed in heavy oil reservoirs after the primary recovery period to displace the heavy oil towards the production well. In comparison with the other enhanced oil recovery processes, waterflooding is certainly cheaper and simpler to employ. However, low recovery factors and poor sweep efficiencies associated with the high mobility difference between the injected water and the heavy oil, set an economic limit to the waterflooding process in heavy oil reservoirs5,6.
- North America > United States (1.00)
- Asia (1.00)
- North America > Canada > Alberta (0.49)
- North America > Canada > Saskatchewan > Williston Basin > Weyburn Field > Mission Canyon Formation (0.98)
- North America > Canada > Saskatchewan > Williston Basin > Weyburn Field > Madison Formation (0.98)
- North America > Canada > Saskatchewan > Williston Basin > Weyburn Field > Forbisher Formation (0.98)
- North America > Canada > Saskatchewan > Williston Basin > Weyburn Field > Charles Formation:Middale Formation (0.98)
Abstract Underground coal gasification (UCG) is an advancing technology that is receiving considerable global attention as an economic and environmentally friendly alternative for exploitation of coal deposits. This technology has the potential to decrease greenhouse gas emissions during the development of coal deposits. The environmental benefits of UCG that promote reduction in greenhouse gas emissions include elimination of conventional mining, coal washing and fines disposal, coal stockpiling and coal transportation activities. Additional benefits include; a smaller surface area requirement with minimal surface disruption; removal of CO2 from the syngas at significantly reduced cost as compared to carbon capture and transport from a power plant; and the potential to reduce CH4 emissions, a potent greenhouse gas. UCG utilizes coalbed methane irrespective of its economic value during the burning process and increases energy efficiency. The CH4 in the product gas is consumed completely during power and/or electricity generation, thus reducing overall methane emissions to the atmosphere. This paper compares greenhouse gas emissions from conventional mining methods to UCG for the exploitation of a coal reserve. The findings indicate that UCG reduces greenhouse gas emissions significantly as compared to other competitive coal exploiting technologies. This research may help in the selection of a suitable method to develop coal deposits when the reduction of greenhouse gases is an essential part of planning. Introduction Underground coal gasification (UCG) is a process that involves burning coal in-situ and converting it into a gaseous product, commonly called syngas. This syngas is composed of mixture of gases at elevated temperatures and pressures and can be utilized for various purposes, including electricity and power generation, heat production, and as a chemical feedstock for a variety of chemical products like ethylene, acetic acid, polyolefin, methanol, petrol and synthetic natural gas (Anon, 1977; Burton, Friedmann, & Upadhye, 2006; Courtney, 2009; Liu, Mallet, Beath, Elsworth, & Brady, 2003). A typical composition of syngas includes H2, CO, CO2, CH4, and some traces of tars, NH3 & H2S. The molar percentage of component gases and concentration of NH3, H2S and other traces depends upon the type of oxidant used (air, oxygen, or steam), site characteristics and coal properties (Ahner, 2008; Walker, 1999). UGC is a rapidly developing technology and several projects in different countries are underway. The global attention gained by UCG is due to its potential for harnessing energy from coal deposits in a manner that is more economical and environmentally friendly than conventional mining methods. As stated by Meany and Maynard, UCG provides several environmental and economic benefits, not only over conventional mining methods but also over surface gasification and even coalbed methane drainage (Meany & Maynard, 2009).
- Materials > Metals & Mining > Coal (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (0.69)
Abstract Eastman Chemical Company has a history of successfully reducing energy intensity. Eastman has received American Chemistry Council (ACC) energy efficiency awards for 18 consecutive years and reduced energy intensity by 38% over 15 years. However, energy efficiency improvements were primarily driven by committed individuals and cost pressures rather than a systemic energy management program. In 2010, Eastman restructured the corporate energy management team and embarked on a journey to build a comprehensive energy management program. Communication tools were developed to build program recognition and provide program structure. Recognition that different tools were needed for different audiences resulted in customized communications directed toward all employees from the operator to the executive level. Examples of tools will be shared with emphasis on communication of energy strategy, guiding principles, and use of business measures to quantify the financial benefits of energy efficiency. A variety of data analysis tools has also been developed to better enable understanding of energy use and to help drive improvements. These tools range from simple checklists to assess the implementation of initiatives at all sites to a complex model that quantifies the primary factors that influence energy intensity. The tools that have been developed will be discussed with a description of applicability. After over a year of concerted effort, Eastman has a defined and structured energy management program. Awareness of the importance of energy efficiency has been increased at all levels. For the first time, in 2011, specific capital funding was provided for a group of designated energy efficiency projects. The tools that have been developed have resulted in a recognized energy management program that yields increased energy efficiency, reduced emissions, and a positive impact on business results. Introduction Eastman Chemical Company has always been mindful of energy usage. However, the commitment to continuous improvement was advanced to a new level in 2010 when the energy program was restructured. Previously led from a procurement focus and limited to information sharing, project lists, and discrete site initiatives, the Energy Program was elevated to an overall corporate program with efforts to increase awareness, corporate initiatives, funding for individual projects and use of available resources. This has been fine-tuned during 2011 through continuous use of the ENERGY STARยฎ Guidelines for Energy Management. The Corporate Energy Management Team, led by a Certified Energy Manager, meets monthly and promotes Eastman's adherence to the Energy Policy, which was updated in 2011 to reflect environmental implications of the energy program and signed and endorsed by Eastman Chairman and CEO, Jim Rogers. This team has representatives from all sites and is comprised of many organizations including engineering, manufacturing, procurement, and utilities.
- Materials > Chemicals (1.00)
- Energy > Power Industry (1.00)
Abstract With increasing energy demand and nations' need to ensure national energy security, the successful application of Carbon Capture and Storage (CCS) to manage carbon dioxide (CO2) emissions from the power sector is a critical part of the world's efforts to mitigate severe global warming. The successful demonstration of the economic and environmental performance of coal-based power with CCS may therefore be critical for allowing continued reliance on coal for electricity generation. The SECARB (Southeast Regional Carbon Sequestration Partnership) Phase III Anthropogenic Test (henceforth called the Project) integrates carbon capture from Alabama Power Company's Plant Barry coal-fired power plant with transport and injection into a deep saline formation for the purpose of demonstrating long-term storage. The Project is one of the world's largest integrated post-combustion coal fired Carbon Capture and Storage (CCS) field demonstration projects. This paper presents how the Project partners have documented risk assessments associated with the CCS chain (capture, transport by pipeline, storage, and monitoring), and discusses how the project plans to manage risks related to the integration of these components. The process of developing the project risk register represents a pioneering effort for CCS projects with capture from a coal-fired power plant, and highlights the need to ensure good communication and shared understanding of risks and opportunities among the project partners. The process and approach to develop the project risk register should therefore help inform future projects about integrated risk assessment and communication.
- Government > Regional Government > North America Government > United States Government (1.00)
- Energy > Power Industry > Utilities (1.00)
- Energy > Oil & Gas > Upstream (1.00)
- North America > United States > Texas > Sabine Uplift > Paluxy Formation (0.99)
- North America > United States > Alabama > Citronelle Field (0.99)
Abstract Aiming at reducing CO2 emissions for ironmaking, we consider and evaluate in this paper the possibility to replace a part of the fossil fuel - coal - usually used to produce pig iron with a renewable one - biomass. Our approach combines life cycle assessment and systems modeling. Steel industry is responsible for more than 6% of the anthropogenic CO2 emissions and reducing the carbon footprint is today a matter of prime importance for iron and steelmakers. Since most of CO2 emissions result from using fossil coal as a fuel and a reductant for ironmaking, using renewable biomass instead looks attractive. Many scenarios (according to the biomass type, the biomass treatment process, the type of injection) are possible and have to be evaluated from environmental, economical and technical feasibility points of view, so that the best option could be identified. First, to check the relevance of a biomass option for an actual pig iron plant located North East of France, the local availability of the biomass was verified and quantified. Then, life cycle assessment (LCA) was used to evaluate the environmental and economical feasibility of the different scenarios. Results of a screening LCA allowed us to proceed to a first selection of scenarios and to determine the hot spots of the whole route, i.e. from raw materials extraction to liquid pig iron. We found that replacing 20 % of the coke with biomass could save around 200 kg of CO2 per metric ton of pig iron produced, which represents a reduction of 10% of the total CO2 emissions of the whole route. Thus, we have already shown that a small substitution of biomass for coke can have a noticeable impact on CO2 footprint. To go further towards an accurate LCA, we are improving the life cycle inventory, through the use of calculated data that precisely respect mass and heat balances. For that purpose, we are currently building mathematical models of the key unit processes (biomass transformation, iron ore sintering, blast furnace) using commercial flowsheeting software. Introduction Since 2005 the main CO2-emitting industries in Europe are subject to CO2 regulations in the form of quota limitations: companies that emit more than authorized quota have to buy extra permits for the CO2 they emit. In 2013, the allowed quota will be be significantly reduced, which entails a best CO2 management for CO2 emitting companies. Since steel industry represents more than 6% of the CO2 world emissions, reducing its carbon footprint is a matter of prime importance. Among the possible solutions to achieve this goal, we consider in this paper the possibility to replace a part of the fossil fuel - coal - usually used to produce pig iron with a renewable one - biomass - in the case of a real plant located in Lorraine, in the North East of France. The classical iron and steelmaking route, a so called "first fusion" route, produces liquid iron from iron ores - mainly made up of iron oxides - and fossil coal. This route is based on three unit processes: the coke oven, the sintering unit and the blast furnace. The coke oven is the process where fossil coal is heated and devolatilized to produce a hard product containing about 90% of carbon, called coke. The sintering unit produces lumps of sintered iron ore from iron ore fines and fossil fuel such as anthracite and coke fines. Eventually, in the blast furnace, the sintered iron ores are reduced with a carbon-monoxide rich gas - result of the combustion and gasification of the coke - to form pig iron - i.e. liquid iron saturated in C - and a large amount of CO2. In order to reduce the CO2 emissions, a solution could be to replace coke - a fossil fuel whose combustion emits 3 tonnes of CO2 per ton of coke - with biomass, which is a renewable and CO2 neutral fuel, as long as the same amount of biomass burnt is planted back.
- Europe > France (0.55)
- North America > United States (0.46)
- Materials > Metals & Mining > Steel (1.00)
- Materials > Metals & Mining > Iron (1.00)
Abstract The effectiveness and efficiency of regulatory and other policy approaches intended to reduce the greenhouse gas emissions from transportation fuels can hinge on the fuel life-cycle analysis (LCA). Emerging regulation has raised urgent questions about both definition and evaluation of life-cycle emissions, and the effectiveness, efficiency and equity of regulatory approaches which use such analyses. This paper focuses on the LCA for transportation fuels from unconventional hydrocarbon sources and associated regulatory issues and implications, and examines these in the context of experience gained in the study of conventional hydrocarbon sources, biofuels, electric vehicles, and other alternatives. Critical issues arise in the regulatory use of life-cycle emissions analysis when comparing different types of fuels, for different types of vehicles, including:Uncertainty in life-cycle emissions - Differences in estimates of the life-cycle emissions for one fuel can exceed the differences in estimates for different fuels; boundaries, accounting, aggregation and accuracy of LCA are each critical and determining issues in its application in regulations. Flexible pathways - In order to incentivize innovation in fuel production, many pathways (with the ability to be altered) are needed to map production from each individual agent, who will each have their own process. Energy security - Regulation to lower the life-cycle emissions is often also intended to improve energy security (e.g. by increasing supplies of indigenous biofuels); however, in the case of unconventional sources of oil such regulations may aggravate energy security. For complex policies, such as those involving LCA - especially where there are international ramifications - much broader dialogue is needed to improve the policy's effectiveness, efficiency and ultimately credibility. INTRODUCTION Emerging regulation of life-cycle greenhouse gas emissions for transportation fuels has raised urgent questions about both definition and evaluation of life cycle emissions, and the effectiveness, efficiency and equity of regulatory approaches which use such analyses. The net emissions from a transportation fuel system depend on the definition of system boundaries, which should be appropriate for its use whether that be to provide insight or for a specific regulatory application. For example, inclusion of emissions from the production of vehicles would add to the system--or life-cycle - greenhouse gas emissions of a transportation fuel. For petroleum-based transportation fuels, the use of the fuel results in about five times the greenhouse gas emissions as in its production (EU JRC 2011, NETL 2008). Consistent application of aggregation, accuracy, and transparency of data are also important when making a comparison between any two production pathways. Critical issues arise in the regulatory use of life-cycle emissions when comparing different types of fuels, for different types of vehicles. It is important to note that a life-cycle assessment tool is not needed for regulatory use if there is a comprehensive policy on emissions across all regions and sectors of society - the cost of emissions would be accounted for where they occur. However, in the absence of a comprehensive policy, accurate and consistent life-cycle assessment can have a useful role when accounting for emissions from the life cycle of a fuel.
Abstract Climate change is becoming most issue discussed in the world since last decade that is believed to occur by the emission of anthropogenic greenhouse-gases in the atmosphere. Carbon dioxide emissions are responsible for the most important greenhouse-gas effects. Therefore developed and developing countries attempt to reduce the CO2 emissions in further decades. Indonesia, as a member of the Kyoto Protocol, plans to reduce CO2 emissions to 26% in 2020. Carbon capture storage (CCS) is one of the technologies to reduce emission and enhanced hydrocarbon recovery. The comprehensive study concerning the technology and application of CCS has been begun in other countries as well as in Indonesia now. Therefore, The Department of Petroleum Engineering of ITB conducts a study concerning the feasibility of CCS application in the petroleum industry. The main purpose of the study is to provide knowledge of CCS system, the effects of impurities on storage operations, and finally the principal storage possibilities in two fields Indonesia, Northwest Java Field and East Natuna. The Northwest Java Field is a back-arc field which consists of many reservoirs-such as Talangakar Formation sandstones, a carbonate reef of Baturaja Formation, carbonate of Upper Cibulakan Formation, and carbonates of Parigi Formation. The most promising formation in Northwest Java field is the Parigi formation.East Natuna Field has similar characteristics with North Java Field, therefore might be suitable also for CO2 injection storage. The research in this paper discussed about feasibility of carbonate formations as CO2 storage. A brief explanation of the geological setting and comparison with other carbonate CO2 storage is also presented. Hopefully, this study will encourage the CCS research and development in Indonesia further.
- Asia > Indonesia > Natuna Sea (0.88)
- Asia > Indonesia > Riau Islands > Natuna Sea (0.87)
- Asia > Indonesia > Java (0.66)
- Asia > Japan > Kansai > Kyoto Prefecture > Kyoto (0.25)
- Geology > Rock Type > Sedimentary Rock > Carbonate Rock (1.00)
- Geology > Geological Subdiscipline (1.00)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock > Mudrock (0.69)
- Geology > Sedimentary Geology > Depositional Environment > Marine Environment > Reef Environment (0.54)
- North America > Canada > Saskatchewan > Williston Basin > Weyburn Field > Mission Canyon Formation (0.99)
- North America > Canada > Saskatchewan > Williston Basin > Weyburn Field > Madison Formation (0.99)
- North America > Canada > Saskatchewan > Williston Basin > Weyburn Field > Forbisher Formation (0.99)
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Abstract Emissions associated to energy generation depend on the source of supply - which varies from polluting oil thermal units to clean renewables. This paper assesses the quality of supply in terms of associated emissions and, more importantly, load management strategies targeting a cleaner energy supply. We propose a framework where each consumer may know the impact of his (her) load management in terms of emissions and the associated economic costs. It will be then possible to clearly identify each consumer's possible "green initiative" action and associated tariffs. We hope this will be the first step towards a transparent, society-supported sustainable future. Index Terms--demand side management, smart green, green energy, carbon management, emission reduction I. INTRODUCTION RENEWABLE energy's main benefits are well known: thermal displacement and associated emission reduction. Moreover, smart grid advances open a whole new world on demand and network management, uncovering to consumers information about the emissions associated to their load and providing them an efficient control over their carbon footprint. The green option, however, comes with a price: renewables may be more expensive than traditional thermal units. It is important to - far from deny it - know the price tag and build an incentive structure able to cover expenses. This work is based on the "smart green" [1] concept and proposes a signal structure able to provide the consumer the whole picture: his impact on emissions and available cleaner options - of course, with the associated price. The model targets initially the non-regulated clients, which concentrate the huge network consumption and are used to monitor and control their peak load. Further extensions could include residential and smaller consumers, after a wide and explanatory campaign.
- Europe (0.29)
- South America > Brazil (0.17)