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Collaborating Authors
19th World Petroleum Congress
Hydrocarbon Fractions From Plastic Wastes For Refinery And Petrochemical Industry
Miskolczi, Norbert (University of Pannonia, Institute of Chemical and Process Engineering) | Bartha, Laszlo (University of Pannonia, Institute of Chemical and Process Engineering) | Angyal, Andras (University of Pannonia, Institute of Chemical and Process Engineering) | Valkai, Istvan (MOL Plc,)
Abstract Each year more than 300 M tons of plastic wastes are generated worldwide. Chemical recycling of waste polymers from households and industrial companies (e.g. HOPE, LOPE, PP, PS etc.) is one of the best methods for their utilization and converting to valuable hydrocarbon products. According to preliminary calculations the cost of refineries could be considerably decreased with recycled wastes. Several oil companies with or without other chemical companies developing plastic waste recycling processes, and other laboratories also work on this field. In our experimental work thermal and thermo-catalytic cracking of different waste polymers were developed in a gas heated horizontal tube reactor using -500'C temperature. Products were separated into fractions of gases, gasoline, middle distillates and heavy oil. It was found that plastic wastes could be converted into gasoline and middle distillates with yields of 2535% and 35-45% depending on the applied parameters of pyrolysis. Yields of lighter hydrocarbons were increasing with temperature and residence time. The structure of hydrocarbons was mainly depending on the raw materials. Products had significant content of unsaturated hydrocarbons, mainly a-olefins, quality of which were improved by laboratory hydrogenation. Gasoline had high octane numbers (80
- Europe (0.30)
- North America > United States (0.15)
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Downstream (1.00)
ABSTRACT Demand for high quality diesel is growing more rapidly than both gasoline and fuel oil in the majority of the world's regional markets. This well known trend, frequently referred to as โdieselisationโ, requires refiners to re-balance production of diesel and gasoline to satisfy market demands. These changes are driving the need for more hydrocracking capacity to increase production of diesel while meeting tighter product specifications. However, in this evolving environment, refiners must not only keep up with changing market demand patterns, but must also drive down costs, grow margins and improve product properties to maintain and improve profitability. Recent advances in UnicrackingTM process and catalyst technologies have focused on raising operating flexibility of hydrocracking complexes by more efficient use of hydrogen and to increase feed throughput while at the same time improving yields and product properties of desired products. The combination of state-of-the-art Unicracking catalysts and innovative hydrocracking process developments ensures that refiners can rebalance their diesel' gasoline production in an efficient and cost-effective manner. Process innovation incorporated in Single Stage, Enhanced Two stage and HyCycle Unicracking designs will be discussed. Enhanced Two stage design has been improved to provide significant increase (up to 5-7 wt%) in distillate yields by incorporating process and catalyst innovations while processing difficult high nitrogen heavy feed stocks. The advances are equally applicable to new investments and to catalyst reloads. This paper will discuss all the latest advances in Unicracking technology, including their successful commercial introduction. It will describe how current hydrocracking unit operators or anyone contemplating the addition of a hydrocracking unit can implement the advances to increase operational flexibility and profitability in their refinery.
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Downstream (1.00)
Abstract Canadian oil sands offer a significant and secure source of crude for the U.S and Canada. While expansion of oil sands upgrading is expected to continue, high capital costs, shortages of key labor, long equipment lead times, uncertainty about new technology, and increased concern about environmental impact have contributed to greater project risk and dampened the optimism for these projects of just a few years ago. New technologies aim to overcome major barriers to bitumen upgrading and extract more value. While all promise breakthroughs, many fail to deliver. A study for the Alberta Energy Research Institute (AERI) and seven other industry participants has winnowed a number of new technology offerings and landed on a handful for further evaluation and demonstration. This independent study carried out as phase 1 of the Alberta Government's Hydrocarbon Upgrading Demonstration Program (HUDP) started with many new technologies and through a technical and economic evaluation process selected the most promising and feasible emerging technologies for further evaluation, development and demonstration. These technologies range from alternatives to delayed coking to integrated petrochemical processes to new processes for gasification of residues. The paper describes the characteristics of these technologies and strategies for optimizing conversion levels, CO2 emissions and economic returns. In the current phase 2 of the HUDP, the Alberta government is providing an initial ๏นฉ100 MM in funding to further develop and demonstrate the commercial readiness of the most promising technologies in partnership with industry. Introduction With the decline in conventional oil and gas, the Canadian Western Sedimentary Basin oil sands will increasingly be seen as a versatile energy resource with diversified products and multiple markets as shown in Figure 1(1). The distribution of oil sands derived products depicted in the diagram should be seen in schematic terms since the market place will determine the actual product mix. To conserve natural gas-currently a major energy source in oil sands development- the industry is increasingly moving towards the use of bitumen residues and coke as sources of energy (heat), power and hydrogen. Extending bitumen upgrading to higher quality synthetic crude is also resulting in production of finished โgreenerโ distillate fuels and there is a growing interest in integrated chemical complexes producing green fuels and petrochemicals in Alberta. The Alberta government wishes to encourage upgrading bitumen to higher value products. In 2005 it established a joint industry-government Hydrocarbon Upgrading Task Force (HUTF) which through a series of workshops identified ways to facilitate growth of value-added developments in Alberta. The history of the HUTF and development of both the Alberta's Value-Added Vision and the associated implementation plans, were outlined in recent papers (2), (3) The Vision developed by the joint government-industry group (paraphrased) is that Alberta "Becomes a world leader in demonstrating and commercializing radically new technologies to utilize Canadian heavy hydrocarbons with positive economic, social and environmental impact". To achieve this vision, creating an environment to support technology development within the province has become a priority.
- Materials > Chemicals > Commodity Chemicals > Petrochemicals (1.00)
- Energy > Oil & Gas > Upstream (1.00)
Abstract EST (Eni Slurry Technology) represents a significant technological innovation in residue conversion and unconventional oil upgrading and will mark a step change in the treatment of the heavy end of the barrel. This new technology, internally developed by Eni, allows the total conversion of the heaviest fraction of the barrel into useful products, mainly transportation fuels, with a great major impact on the economic and environmental valorisation of hydrocarbon resources. EST employs nano-sized hydrogenation catalysts and an original process scheme which allow complete feedstock conversion to valuable distillates or its upgrading to synthetic crude oil with a substantial API gravity gain, avoiding the production of residual by-products, such as pet-coke or heavy fuel oil. Since the 1990's, the technology has been successfully tested on both laboratory and pilot scales. Following the positive results obtained at this scale, Eni decided to build a 1200 bpd Commercial Demonstration Plant (COP) within its Taranto refinery. The plant was completed and successfully started up in the third quarter of 2005. Since then, the COP unit operation has allowed the successful test of EST performance on heavy feedstocks from around the world (Russia, Venezuela, Mexico, Middle East and Canada), confirming the great flexibility of the process. The peculiar characteristics of EST in terms of yield, products quality, absence of undesired by-products and feedstock flexibility constitute its superior economic and environmental attractiveness. EST can offer additional margins in the range of 3-5 ๏นฉ/bbl of feedstock over current conversion technologies, which can be crucial for the exploitation of unconventional oil reserves. The positive results obtained to date have encouraged the decision to host the first full scale industrial plant based on this new technology at Eni's Sannazzaro refinery.
- Asia (1.00)
- North America > Canada > Alberta (0.68)
ABSTRACT 26th January, 2001 was a black Friday for India. The country was celebrating Republic Day and everyone was in a joyous and holiday mood. But nature and fate willed otherwise. It was at its cruel best. As the clock struck 8:46 a.m., a massive earthquake, the worst ever to hit the country since Independence, measuring 8.1 on the Richter Scale devastated Gujarat State. For 45 long seconds, the deathquake violently rocked most parts of the State reducing cities and towns to rubble and entombing several thousands in the debris. Thousands terraced under the crushing weight of the concrete, which was once their homes. So large was the number of those who lost their lives, that there was no space in the crematoriums to accommodate the bodies, and relatives/friends were left with no option but to cremate their loved ones even on the sides of the roads. The devastating Earthquake had tremendous impact on the entire oil industry of the state. Storage tanks started tilting, pipelines came out of pedastals, pipeline flanges leaking endengered the possibility of fire. Apart from collapsing of various civil structures, storage tanks sank more than 300 mm inside the ground. Power and communication systems in the state totally collapsed. Entire industries were caught unaware. All disaster management plans failed. Most of the employees were busy in finding out the well being of their family members. The most vulnerable task was to commence supply of petroleum products to quake affected people. The killer quake caused a lot of destruction, havoc and grief but it did not succeed in breaking the determination and resolve of our INDIANOIL men in restoring supplies of crucial petroleum products to the affected areas. Almost every retail outlet was affected by the earthquake. Those less damaged began operating within minutes of the quake, with the assistance of a generator. Others, who unfortunately suffered severe damages were helped by Indian Oil's territorial army personnel to recover and commence supplies to motorists. Within a couple of days, all the retail outlets were back in action. Indian Oil ensured that there was sufficient stock of LPG Cylinders with all distributors and who ever approached the distributors with an empty cylinder was given a refill. Despite the distributors godowns being damaged, supplies of LPG Cylinders went on. Supplies were also rushed from other locations by road. Immediate actions were taken with the help of available manpower to stop leakages, keep fire fighting teams ready for any eventualities, commencement of loading of tank trucks specially with kerosene for rescue supplies. All pipelines were de-pressurized. All post quake activities were carrried out and Indian Oil was successful in overcoming the effects of the earthquake in theshortest possible time. Total financial loss to the company due to the earthquake was about 65 Million USD.
- Energy > Oil & Gas > Downstream (1.00)
- Government > Regional Government > Asia Government > India Government (0.34)
ABSTRACT The objective of half reduction of world emissions of GES in 2050 in the aim of a stabilization at 550 ppm of concentration of greenhouse gases in the atmosphere, led to consideration of projects on carbon capture and storage (CCS) at an international level. At the current international energy context the option of capture and geological storage of CO2 is more and more often mentioned during international discussions as a possible Kyoto Protocol mechanism of flexibility generating credits (CERs, ERUs, and for Europe EUA). However, nowadays, these projects of CCS are not completely recognized and do not generate credits on the market, neither on the International market nor on the European market EU-ETS. Discussions are in progress at the European level, and well under way in the framework of the Article 24 of the Quotas Directive revision: modalities to recognize these projects are expected. Their impacts on the management of the CO2 market and consequently on the evolution of the CO2 prices are inevitable. This paper reviews the implications of CCS projects announced on the EU-ETS market:โAn inventory of existing and planned international CCS projects in term of annual volumes of CO2 reductions announced from 2008 and throughout the life expectancy of these projects is made (with distinction between projects hosted by Annex- I and non-annex-I countries). โAt the European level, and the European Commission's declaration of none coal power plants without CO2 capture from 2020: consequences of increasing volumes of CO2 avoided and their relative impact in volume on the CO2 regulated market of quotas are examined. As soon as 2008 some projects could appear on the CO2 market. Today, the main actors of CCS projects ask for a stable and relatively high CO2 price on the market to be able to reach projects at industrial level. Volumes of CO2 reductions expected by CCS projects, in case of total recognition on the European market, could reversely and on the long term influence the evolution of the European market and its CO2 price level.
- Europe (1.00)
- North America > Canada (0.29)
- Asia > Japan > Kansai > Kyoto Prefecture > Kyoto (0.26)
- Law > Environmental Law (1.00)
- Government > Regional Government > Europe Government (1.00)
- Energy > Power Industry (1.00)
- (2 more...)
- Oceania > Australia > Victoria > Otway Basin (0.99)
- Oceania > Australia > South Australia > Otway Basin (0.99)
- Asia > China > Qinshui Basin (0.99)
- (2 more...)
Abstract To provide a sufficient and stable supply of natural gas, producers seeking to increase reserves and governments striving to be more energy independent are exploring unconventional gas sources. To date, most unconventional gas recovery has occurred in the United States close to high energy-use areas; however, rapidly developing countries or countries that do not have easily recoverable hydrocarbons are evaluating these unconventional gas resources to help facilitate economic growth. Producers are now considering gas reserves not previously considered reservoir quality'lowpermeability sandstone, carbonates, shales, and coal seams. Case histories presented in this paper illustrate various new technologies used in exploiting commercial, gas-bearing intervals in resource plays. The discussion examines integrated technologies that can be applied either offshore or on land to produce difficult resources. The combined benefits and drivers of the technologies include:Increased production. Operational simplicity. Lower recovery cost. Increased gas deliverability relative to high energy use areas. In dealing with gas in unconventional reservoirs, a holistic technological approach should be taken throughout the exploration/development cycle. Within the individual well, best practices and lessons learned should be taken from the initial reservoir exposure to drilling/completion, production, and renewal activities. Renewal activities defined as re-stimulation in resource plays can provide significant recovery upside. Continuous information feedback and application of lessons learned is needed to enable better decision-making in the quest to recover unconventional gas reserves.
- Geology > Rock Type > Sedimentary Rock > Organic-Rich Rock > Coal (0.88)
- Geology > Rock Type > Sedimentary Rock > Clastic Rock (0.57)
- North America > United States > Texas > Fort Worth Basin > Barnett Shale Formation (0.99)
- North America > United States > Texas > Anadarko Basin > Granite Wash Formation (0.99)
- North America > United States > Oklahoma > Anadarko Basin > Cana Woodford Shale Formation (0.99)
- (2 more...)
Abstract The objective of the presentation is to provide an introduction to InSAR technology and its applications for reservoir monitoring. InSAR (Interferometry for Synthetic Aperture Radar) technology is a spaceborne measurement method, able to detect ground motion with millimetric exactness using radar satellite images. Measurements are taken remotely from the space without any installations on the site, achieving a high measurement density. Therefore it is a very cost efficient tool to measure ground motion in even remote areas in most areas of the world. Altamira Information has developed its own advanced differential interferometric chain able to process several raw radar images to achieve millimetric ground motion measurements. Results are provided in GIS format and can be received and analysed by reservoir engineers remotely without the need for site visits. Ground motion monitoring with radar images can contribute to oil & gas reservoir monitoring in several ways: For oil and gas extraction areas, InSAR ground motion results support site safety since risk areas can be identified at an early stage. For SAGO extraction, millimetric ground motion monitoring is able to contribute to production efficiency: By mapping ground motion elevation changes over the whole SAGO extraction area, InSAR measurements can aid the assessment of whether the pressure of SAGO injection is correctly distributed over the area. For gas storage areas, InSAR can contribute to an evaluation of the storage stability, since millimetric surface uplift could be an indicator for a potential storage leak. Radar image based measurements can be conducted standalone at reservoir monitoring sites; it is also possible to combine InSAR measurements with GPS measurements or ground levelling methods. In order to illustrate the value added of this spaceborne technology with concrete examples, the presentation will include some case studies.
- Reservoir Description and Dynamics > Formation Evaluation & Management (1.00)
- Reservoir Description and Dynamics > Improved and Enhanced Recovery (0.98)
- Data Science & Engineering Analytics > Information Management and Systems (0.88)
- Reservoir Description and Dynamics > Reservoir Characterization (0.69)
ABSTRACT The Canadian Long Lake Project is the first project to integrate Steam Assisted Gravity Drainage (SAGO), cogeneration and onsite upgrading in the Athabasca Oilsands and globally. The SAGO project alone is the largest single phase project developed to date. The upgrader produces a synthetic crude designed to be a substitute for globally declining light sweet crude supply and also produces a synthetic gas which is used to generate steam and electricity making the overall project largely energy self-sufficient. The Athabasca Oilsands are one of the largest accumulations of oil in the world with estimated bitumen in place of 1.7 trillion barrels. Until recently, the primary means of extracting bitumen has been surface mining; however, over 80% of the bitumen is buried too deep to be economically mined. The commercialization of SAGO has provided a technical solution to extract the vast majority of the resource. The Athabasca Oilsands are now the largest potential source of future reserves outside of OPEC. Traditionally, the commercialization of SAGO had three remaining major economic challenges: the cost of natural gas to generate steam, the cost of diluent to blend the bitumen for transportation to refineries and the price received for raw bitumen. A number of primary and secondary upgrading processes were reviewed over several years. The Long Lake Project will take 6-100 API gravity oil and upgrade it to a 39APIo synthetic oil. The integrated solution developed to attain this final product for the Long Lake Project addresses these major economic challenges. The result is that the Long Lake project is largely self-sufficient with respect to natural gas; it exports co-generated power to market and produces a premium synthetic crude which requires no diluent and is a substitute for declining production of light sweet crude oil. Future phases of development will be of similar design and will allow leverage of the knowledge and experience gained on the first phase.
- Asia > Middle East (0.94)
- North America > Canada > Alberta (0.30)
- North America > United States > Texas (0.28)
- North America > Canada > Saskatchewan > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > Canada > Northwest Territories > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- North America > Canada > Manitoba > Western Canada Sedimentary Basin > Alberta Basin (0.99)
- (3 more...)
Abstract There is broad consensus that climate change is real and that we need to act quickly to reduce greenhouse gas (GHG) emissions to curtail the negative impacts on our environment. In December 2007,180 countries at the United Nations Climate Change Conference in Bali, Indonesia agreed that tackling climate change requires coordinated international action. National governments are looking to replace the Kyoto agreement once it expires in 2012; however, it is unlikely that a truly global policy mechanism will emerge in the foreseeable future. Policy makers accept emission trading schemes as an effective policy tool that offer a lower cost, market-based approach to abatement. Emissions trading schemes that include offset projects in developing markets are considered a key tool for supporting wealth and technology transfers to developing countries - where GHG emissions are rapidly increasing although per capita emissions remaining low, and where governments lack the financial resources to develop comprehensive abatement programs. Driven by sovereign risk considerations, governments are designing national or regional trading schemes that satisfy local policy objectives. It is increasingly likely that, for the foreseeable future, instead of a single global emissions trading scheme, there will be a patchwork of schemes, as a number of mandatory and voluntary schemes are now operating or being developed around the world. Many governments involved in developing emissions trading schemes want to link their scheme with others, to achieve the benefits of a larger market. Companies are at different stages of capability with respect to dealing with emissions markets. Entities in Europe, for example, tend to have more developed capabilities as a result of their experience with the European Emissions Trading Scheme (EU ETS). However dealing with linked schemes will present increased challenges and opportunities for most entities as both strategic and operational implications must be addressed. This paper presents: an overview of emissions trading schemes and the ways in which they can be linked an overview of consequences of linking schemes the implications of linked emissions trading schemes for business
- Europe (1.00)
- North America > United States (0.47)
- Asia > Japan > Kansai > Kyoto Prefecture > Kyoto (0.24)
- Asia > Indonesia > Bali (0.24)
- Law > Environmental Law (1.00)
- Banking & Finance > Trading (1.00)