Day 1 :
Keynote Forum
Hartmut R Fischer
TNO Technical Sciences, The Netherlands
Keynote: Asphaltene and wax precipitation – Common principles of structuring
Time : 9:15-10:00
Biography:
Hartmut R Fischer is a Senior Research Scientist in TNO Technical Sciences and monitors materials’ performance and as such connected with all kinds of materials, their testing and evaluation with a focus on materials under extreme environments and the high end equipment applications. His areas of current activities are the assessment of pavement durability as well as adhesion and surface studies, the study and design of self-healing systems, the investigation and understanding of the micro structure of building materials leading to the design of modern building materials for applications under extreme circumstances. He acts as co-Promoter for PhD students and Mentor of Post-Docs at the TU Eindhoven and Delft in the areas polymer nanocomposites, self-healing systems and transport in porous media. He is also a referee for the German and Dutch Research Council as well as for about 40 scientific journals. He has authored 185 refereed publications, 35 patents and 8 book chapters.
Abstract:
Asphaltenes are a complex mixture of different molecules with similar chemical characteristics which are insoluble in aliphatic solvents (e.g. heptane) but soluble in aromatic ones (e.g. toluene). However, being also known as the ‘cholesterol’ of crude oil, they precipitate, adhere to surfaces and, in the worst cases, cause costly pipe blockages and alter the wetting characteristics of mineral surfaces within the reservoir, hindering oil recovery efficiency. Similar effects are also observed with respect to waxes. Even at very low concentrations in ‘good’ solvents, both still have a strong tendency to form nanoaggregates or nanocrystallites which transfer to micro- and macro-aggregates whose structure and formation remain largely unknown despite much research. Aggregation proceeds from specific strong interaction sites located at the periphery of the asphaltene molecules. They drive the reversible association in two-dimensional sheets, a morphology which is consistent with reported scattering and viscosity data. Precipitation eventually occurs, determined by van der Waals attractions between aggregates, when the solubility parameter of the solvent is shifted. In our current research, we have focused on the several steps to tackle this problem which can heavily impact the economic value of a project, especially in harsh sub-sea environments, where deposition can halt production altogether. For example, intervention costs for asphaltene removal for a land-based well up to $0.5 MM US translates to more than $3 MM US for off-shore well production, and the economic loss as a result of lost/delayed production can amount to $1.2 MM US per day. The ability to predict the occurrence and magnitude of asphaltene deposition in wellbores is critical to forecast the related flow assurance challenges for deep and ultradeep water production. We therefore have the goal to find a solution (chemical, mechanical or otherwise) namely to: a) Understand the issues and help characterize the problem, b) Prevent or inhibit deposition (asphaltene alone or in combination
Keynote Forum
Fabrizio Paolacci
Roma Tre University, Italy
Keynote: Seismic isolation of elevated steel storage tanks by sliding concave bearings
Time : 10:00-10:45
Biography:
Fabrizio Paolacci graduated in Civil Engineering in 1992 at the University of Rome "La Sapienza" and completed his PhD in Structural Engineering in 1997. He is currently working as an Assistant Professor in Structural Engineering at University Roma Tre, Department of Engineering. He gained a long standing experience in the management of research projects about experimental assessment of the seismic response of structures. He is currently PI of many European projects. From 2008 to 2013, he assumed the role of Scientific Coordinator of the Laboratory of Testing Materials and Structures of the Department of Structures of the University Roma Tre. He has received a Fellowship provided by CNR (National Research Council) for a research activity of six months at the Department of Civil and Environmental Engineering of University of California at Berkeley from September 1999 to February 2000 as a Visiting Scholar. He is author of more than 100 publications on international peer-reviewed journals and conferences.
Abstract:
Liquid steel storage tanks are strategic structures for industrial facilities and have been widely used both in nuclear and non-nuclear power plants. Typical damage to tanks occurred during past earthquakes such as cracking at the bottom plate, elastic or elastoplastic buckling of the tank wall, failure of the ground anchorage system and sloshing damage around the roof, etc. Due to their potential and substantial economic losses as well as environmental hazards, implementations of seismic isolation and energy dissipation systems have been recently extended to liquid storage tanks. Although the benefits of seismic isolation systems have been well known in reducing seismic demands of tanks; however, these benefits have been rarely investigated in literature in terms of reduction in the probability of failure. In this paper, a vulnerability-based design approach of a sliding concave bearing system for an existing elevated liquid steel storage tank is presented by evaluating the probability of exceeding specific limit states. Firstly, nonlinear time history analyses of a three dimensional stick model for the examined case study are performed using a set of ground motion records. Fragility curves of different failure modes of the tank are then obtained by the well-known cloud method. In the following, a seismic isolation system based on concave sliding bearings is proposed. The effectiveness of the isolation system in mitigating the seismic response of the tank is investigated by means of fragility curves. Finally, an optimization of design parameters for sliding concave bearings is determined based on the reduction of the tank vulnerability or the probability of failure.
Keynote Forum
Bjørn Kvamme
University of Bergen, Norway
Keynote: Combined CO2 storage in hydrate with simultaneous release of CH4 and limitations of adding N2 to the CO2
Time : 11:15-11:45
Biography:
Bjørn Kvamme obtained his MSc in Chemical Engineering (1981) and PhD in Chemical Engineering (1984) from the Norwegian University of Technology and Natural Sciences. After a short period with SINTEF and two years at Bergen University College, he was appointed as full Professor in 1987 and started education of MSc and PhD in Process Technology in Telemark. He is appointed as a Professor in Gas Processing at the Department of Physics, University of Bergen in March 2000. He is the author/co-author of 422 publications during last 25 years, of which 148 are in good international scientific journals. He has 2270 citations as per May 1, 2017, and has presented numerous papers at international conferences.
Abstract:
Huge resources of energy in the form of natural gas hydrates are widely distributed worldwide in permafrost sediments as well as in on shore sediments. A novel technology for combined production of these resources and safe long-term storage of carbon dioxide is based on the injection of carbon dioxide into in situ methane hydrate-filled sediments. This will lead to an exchange of the in situ methane hydrate over to carbon dioxide- dominated hydrate and a simultaneous release of methane gas. Recent theoretical and experimental results indicate that the conversion from natural gas hydrate to carbon dioxide hydrate and mixed carbon dioxide/methane hydrate follows two primary mechanisms. Direct solid state transformation is possible, but very slow. The dominating mechanism involves formation of a new hydrate from injected carbon dioxide and associated dissociation of the in situ natural gas hydrate by the released heat. Nitrogen is frequently added in order to increase gas permeability and to reduce blocking due to new hydrate formation, and will as such also reduce the relative impact of the fast mechanism on the conversion rates. In addition to carbon dioxide, other sour gases, such as hydrogen sulfide, may follow the carbon dioxide from the sour gas removal process. Hydrogen sulfide is a very aggressive hydrate former. It is abundant in various amounts in thermogenic hydrocarbon systems. In this work, we investigate the sensitivity of possible additions of hydrogen sulfide in carbon dioxide/nitrogen mixtures, and how the ability to form new hydrate changes with the additions of hydrogen sulfide. This analysis is applied to four case studies: (1) Bjørnøya gas hydrate basin, (2) the Nankai field in Japan, (3) the Hikurangi Margin in New Zealand, and (4) a gas hydrate basin in South-West Taiwan. The hydrate saturations found in these fields vary over a range from 25−80%. Pressures range from 4−22.6 MPa and temperatures from 275.15−292.77 K. For all these ranges of conditions, even 1% H2S will substantially increase the ability to form new hydrate from an injected CO2/N2 mixture containing H2S. Except for the most shallow of the reservoirs (Bjørnøya) 1% H2S results in formation of a new hydrate for all concentrations of CO2 in N2 above 1%. Implementation of results from this work into a reservoir simulator is a natural follow-up which can shed light on the macroscopic consequences in term of possible local blocking of the flow due to content of H2S. The mass transport, mass balances, and energy balances in a reservoir simulator are also needed for a more detailed evaluation on how the content of H2S and CO2 changes over time and location in the reservoir due to various processes in addition to hydrate formation. H2S and CO2 dissolves significantly in pore water, and also adsorbs well on various sediment minerals.
- Petrochemistry | Petroleum processes | Natural hazards in Petroleum industry | Sustainable Usage
Location: 1
Chair
Bjørn Kvamme
University of Bergen, Norway
Session Introduction
Bjørn Kvamme
University of Bergen, Norway
Title: Combined CO2 storage in hydrate with simultaneous release of CH4 and limitations of adding N2 to the CO2
Biography:
Bjørn Kvamme obtained his MSc in Chemical Engineering (1981) and PhD in Chemical Engineering (1984) from the Norwegian University of Technology and Natural Sciences. After a short period with SINTEF and two years at Bergen University College, he was appointed as full Professor in 1987 and started education of MSc and PhD in Process Technology in Telemark. He is appointed as a Professor in Gas Processing at the Department of Physics, University of Bergen in March 2000. He is the author/co-author of 422 publications during last 25 years, of which 148 are in good international scientific journals. He has 2270 citations as per May 1, 2017, and has presented numerous papers at international conferences.
Abstract:
Huge resources of energy in the form of natural gas hydrates are widely distributed worldwide in permafrost sediments as well as in on shore sediments. A novel technology for combined production of these resources and safe long-term storage of carbon dioxide is based on the injection of carbon dioxide into in situ methane hydrate-filled sediments. This will lead to an exchange of the in situ methane hydrate over to carbon dioxide- dominated hydrate and a simultaneous release of methane gas. Recent theoretical and experimental results indicate that the conversion from natural gas hydrate to carbon dioxide hydrate and mixed carbon dioxide/methane hydrate follows two primary mechanisms. Direct solid state transformation is possible, but very slow. The dominating mechanism involves formation of a new hydrate from injected carbon dioxide and associated dissociation of the in situ natural gas hydrate by the released heat. Nitrogen is frequently added in order to increase gas permeability and to reduce blocking due to new hydrate formation, and will as such also reduce the relative impact of the fast mechanism on the conversion rates. In addition to carbon dioxide, other sour gases, such as hydrogen sulfide, may follow the carbon dioxide from the sour gas removal process. Hydrogen sulfide is a very aggressive hydrate former. It is abundant in various amounts in thermogenic hydrocarbon systems. In this work, we investigate the sensitivity of possible additions of hydrogen sulfide in carbon dioxide/nitrogen mixtures, and how the ability to form new hydrate changes with the additions of hydrogen sulfide. This analysis is applied to four case studies: (1) Bjørnøya gas hydrate basin, (2) the Nankai field in Japan, (3) the Hikurangi Margin in New Zealand, and (4) a gas hydrate basin in South-West Taiwan. The hydrate saturations found in these fields vary over a range from 25−80%. Pressures range from 4−22.6 MPa and temperatures from 275.15−292.77 K. For all these ranges of conditions, even 1% H2S will substantially increase the ability to form new hydrate from an injected CO2/N2 mixture containing H2S. Except for the most shallow of the reservoirs (Bjørnøya) 1% H2S results in formation of a new hydrate for all concentrations of CO2 in N2 above 1%. Implementation of results from this work into a reservoir simulator is a natural follow-up which can shed light on the macroscopic consequences in term of possible local blocking of the flow due to content of H2S. The mass transport, mass balances, and energy balances in a reservoir simulator are also needed for a more detailed evaluation on how the content of H2S and CO2 changes over time and location in the reservoir due to various processes in addition to hydrate formation. H2S and CO2 dissolves significantly in pore water, and also adsorbs well on various sediment minerals.
Robert Kester
Rebellion Photonics, USA
Title: Automated gas leak detection and monitoring using a Gas Cloud Imaging (GCI) video camera system
Biography:
Robert Kester is the Chief Technology Officer and Co-Founder of Rebellion Photonics, a high-tech company that delivers fully autonomous video monitoring solutions for the oil & gas industry based on their novel snapshot hyperspectral imaging technology. He has 15 years of optics experience, 10+ publications, 4 patents and 5 more pending. He has completed his MSc from the College of Optical Sciences, University of Arizona and PhD in Bioengineering from Rice University.
Abstract:
Current gas leak detectors are ineffective safety monitoring and decision making tools. Alarms are often difficult to verify and require significant resources (instrumentation and trained personnel) to identify the size, direction and origin of leak. In bad weather conditions, it becomes even more difficult to find the leak and verify that there had been a true positive alarm and not a false positive alarm. Due to these difficulties, often times problematic gas leak detectors are de-tuned rendering them useless and/or ignored until more resources can be brought in to find the leak. This hinders the decision making process and increases risk and lost product. To address this need, Rebellion Photonics has developed an innovative, fully automatic, gas leak detection video camera system that can be deployed around rigs and refineries for continuous (24/7) monitoring. Instead of providing a single alarm value like current gas leak detectors, the gas cloud imaging (GCI) camera provides operators with easy-to-interpret false-colored video showing the location, direction, size and concentration of a gas leak. The GCI camera is a true decision making tool that can operate in all weather conditions as well as day and night as it does not require any external light sources. The camera's technology is based on Rebellion Photonics' patented snapshot hyperspectral imaging approach which can capture a gases unique infrared absorption spectral fingerprint from any point in an image instantly. In this presentation, we will present the capabilities of the GCI camera; describe the technology and present examples of gas leaks that have been detected by the GCI camera system.
Ilmer Yu Hasanov
Bashkir State University, Russia
Title: Fast acting sector gates (ZKSsh) - A new stage in petrochemical equipment development
Biography:
Ilmer Yu Hasanov has broad expertise in development of fundamental industry-specific regulatory documents as well as in design of environment protection equipment and technologies for oil production and transport. He has offered and developed an integrated emergency response and prevention system on oil pipelines including identification of regularities at evaporation of the oil spilled on water bodies and a method for minimization of evaporation and fire & explosion hazard; methods and technology for displacement and collection of oil spills on swamps; identification of regularities at relocation of petro polluted soils; development of NGL fractionation methods and technology at oil and gas fields; methods and technology of containment and collection of oil from water surface. He has founded the Scientific and Production Center Sherik LLC for development, design and production of new, upgraded and commercial equipment for oil and gas production and pipeline transport - the only scientific organization in Salavat.
Abstract:
Productivity of the intermittently operating equipment considerably depends on duration of opening and closing actions of its closures. At petrochemical facilities to the intermittently operating equipment belong filters, chambers for launching and receiving of cleaning, inspection, batching and displacement pigs, arresters (dust separators), hatches/manholes of different vessels and apparatuses, and many others as well. Fixing to the equipment of closures to be opened/closed repeatedly by means of pins and nuts, applied for long years, has so far became obsolete. It is metal-intensive, labor-consuming, extremely inconvenient in operation, especially in case of big diameter branch pipes and high pressures. So, for example, the mass of an apparatus’ DN 1400 flanged coupling for operating pressure 10 MPas makes about 8200 kg. Whereas fixing is done using 32 pieces of M80 pins 22 kg each, and opening or closing, as a matter of experience takes at least one shift work for a crew of highly qualified assembling fitters. Manufacturing of such equipment has significantly declined. In the last decades, in construction and revamping of petrochemical facilities instead of bolted connections of covers and manholes are widely used different types of fast-acting gates/closures. The purpose of this study is to analyze the most used fast acting gates for covers and hatches/manholes of pipelines deadlock sections, chambers and apparatuses, their advantages and shortcomings. It is shown that to strict requirements of reliability, convenience of manufacture and operation fully comply ZKSsh type new generation fast acting sector gates. The executed work stages during development of the given fast acting sector gates and existing difficulties are presented, the tasks on their global widespread implementation are set.
Young Han Kim
Dong-A University, South Korea
Title: Energy saving in atmospheric crude process using modified crude distillation units
Biography:
Young Han Kim has many years’ experience in process development towards industrial applications. Especially energy-efficient processes are among his current developments. Distillation and extraction processes of large processing throughput are the projects of his recent publications. His experience includes not only simulation studies, but also distillation experiments and process control practices.
Abstract:
Crude oil is the starting material for petroleum and petrochemical processes, and contains hundreds of hydrocarbons used as fuel and feedstock in the chemical processes. A crude distillation unit (CDU) is the first step in the refinery processing of crude oil, which consumes a large amount of energy due to the large processed amount and the high processing temperature. Refinery engineers handling the crude oil have many years of experience using the CDU, and therefore, the distillation columns currently in operation are considered to be optimized and consume minimum amount of energy. When a typical crude distillation unit is compared with a common distillation column processing multiple products, its operation is quite different with respect to the separation process of benzene, toluene, and xylene mixtures as an example. The common arrangement of distillation columns is in a direct or indirect sequence, in which the products are produced one by one in the column until the final two products, in the sequence of component volatilities. In contrast, the CDU processes all the 5 products in a single column, which lowers its thermodynamic efficiency due to the mixing of the feed and products. The problem of the large energy demand associated with the single column operation of the conventional CDU was solved with the two-column operation, a prefactionator and the main column, in the proposed CDU. The two-column operation reduces feed tray mixing, and thus raises the thermodynamic efficiency of the CDU. In the present study, the performance of the proposed CDU was examined by comparing the energy consumption, investment and utility costs, and thermodynamic efficiency with those of the conventional CDU. A novel crude distillation system was proposed for reduced energy use. The problem associated with the single-column operation of the conventional crude distillation unit was solved with a two-column operation. The single column operation reduced the thermodynamic efficiency of the system due to the feed tray mixing requiring more energy. The computed results of performance evaluation indicate that the proposed system saved 35% of heating duty over the conventional system, with a reduction in cooling duty of 23%. The economic analysis shows that a 22% decrease in investment cost and a 39% reduction in utility cost were found from the proposed system compared with the conventional system. The comparison of thermodynamic efficiency demonstrates a 5% improvement over the conventional system.
Qi Li
China University of Geosciences, China
Title: Characteristics and microstructure of tight gas reservoir in the Upper Triassic Sichuan Basin, Western China
Biography:
Qi Li is currently working as a Professor of China University of Geosciences, China. His research is mainly focused on characterization and modeling of fractured reservoir, sequence stratigraphy and marine sciences. He has earned his BS degree in Geology from Chengdu College of Geology in 1992 and obtained PhD in Sedimentology from Chengdu University of Technology in 1999. He has completed his Postdoctoral studies on Petroleum Geology and Marine Science in China University of Geosciences and China University of Ocean from 1999 to 2006.
Abstract:
The western Sichuan Basin is a foreland basin formed in the Late Triassic at the front of the Longmen Mountain in the western Sichuan Province of China. The Upper Triassic Xujiahe Formation in the basin is an ultralow-permeability and low-porosity tight sandstone and shale gas reservoir. Tight gas reservoirs are often defined as gas-bearing sandstones or carbonates having in situ permeabilities to gas less than 0.1 mD. This article offers an integrated approach to describe microstructure characteristics of a tight sandstone and shale gas reservoir. In particular, the primary and secondary porosity of tight gas sandstone is identified and quantified in three dimensions using X-ray Nano-CT imaging and visualization of core material at the pore scale. 3D images allow one to map in detail the pore and grain structure and interconnectivity of primary and secondary porosity. Once the tomographic images are combined with SEM images from a single plane within the cubic data set, the nature of the secondary porosity can be determined and quantified. In situ mineral maps measured on the same polished plane are used to identify different microporous phases contributing to the secondary porosity. Once these data sets are combined, the contribution of individual clay minerals to the microporosity, pore connectivity and petrophysical response can be determined. Insight into the producibility may also be gained. This illustrates the role 3D imaging technology can play in a comprehensive reservoir characterization program for tight gas. Three types of microfractures, intragranular, grainedge and transgranular microfractures, developed in the tight-gas sandstones of the western Sichuan Basin. Microfracture formation reflects tectonism, overpressuring, and diagenetic processes. Tensional microfractures related to overpressure formed in the Middle-Late Cretaceous. The existence of overpressure reduced effective stress, promoting opening-mode fracture growth. The existence of tension fractures can also be used as an indicator of ancient overpressure in a sedimentary basin. Diagenetic fractures formed from the Late Triassic, when the foreland basin of the western Sichuan Basin formed to the Early Cretaceous.
Bjørn Kvamme
University of Bergen, Norway
Title: Impact of rusty pipelines on risk of hydrate formation
Biography:
Bjørn Kvamme obtained his MSc in Chemical Engineering (1981) and PhD in Chemical Engineering (1984) from the Norwegian University of Technology and Natural Sciences. After a short period with SINTEF and two years at Bergen University College, he was appointed as full Professor in 1987 and started education of MSc and PhD in Process Technology in Telemark. He is appointed as a Professor in Gas Processing at the Department of Physics, University of Bergen in March 2000. He is the author/co-author of 422 publications during last 25 years, of which 148 are in good international scientific journals. He has 2270 citations as per May 1, 2017, and has presented numerous papers at international conferences.
Abstract:
The North Sea is covered by close to 8000 km of pipelines transporting hydrocarbons. Pressures are high and temperatures are generally low. Temperatures can be as low as 272 K in the north, due to seawater salinity, and rarely exceeds 279 K for the southernmost pipelines. The most common procedure for hydrate risk analysis involves calculation of water dew-point for a gas mixture containing water. Pipelines are normally covered by rust even before they are put in place. Rust is a mixture of iron oxide and one of the most stable is Hematite, Fe2O3. Due to the distribution of partial charges on the Hematite surface, adsorbed water will be highly structured, resulting in low chemical potentials and low adsorption energy for the water molecules. The adsorbed water on the walls is thermodynamically cold in terms of the functional derivative of the internal energy of the adsorbed layer with respect to the entropy of the adsorbed layer. This fact adds on top of the walls being the coldest region of the pipeline due to the cooling towards outside seawater. The low chemical potential of adsorbed water and incompatibility of partial charges between Hematite and hydrate surface will not permit hydrate to directly attach to the surface of the walls but the walls can serve as nucleation surfaces and hydrates formed can be bridged by structured water layers to the rusty pipeline surface. Earlier studies for various simple hydrocarbon systems indicate that the tolerance for water content based on dew point might be 20 times higher than the water content corresponding to water adsorbing from gas onto solid Hematite surface. In this study, we apply a similar comparison for a real hydrocarbon mixture for the first time, using composition data which is openly available for the troll gas from the North Sea. Since the average chemical potential of adsorbed water can be as much as 3.4 kJ/moles lower that liquid water chemical potential route to hydrate formation dominates totally in determining the risk of water dropping out from the gas and eventually forms hydrate.
Aleksey Kuznetsov
Marine Arctic Geological Expedition, Russia
Title: Discovery of a new potential hydrocarbon bearing province in the north-west of the Russian arctic, creation of its generalized geological model and cost estimate of mineral resources
Biography:
Aleksey Kuznetsov has graduated from the Kola Branch of the Petrozavodsk State University in 2001 at Applied Physics Department, as a Geophysicist. From 2002 to 2007, he worked as a Geophysicist in the Federal State Unitary Enterprise Arktikmorneftegazrazvedka. He has performed integrated geophysical surveys in the boreholes at the jack up drilling rig Murmanskaya and on Kolguyev Island. Since 2008, he has been working as a Geophysicist in JSC MAGE.
Abstract:
The report presents generalization results of integrated geophysical surveys, including 2D CMP reflection works, above-water gravity measurements and differential hydromagnetic measurements in the volume of 30000 LKM carried out by JSC MAGE under order of the Federal Subsoil Resources Management Agency (Rosnedra) during 2006-2012. As a result of the geophysical data integrated interpretation, one recognized main unconformities and seismic sequences characterizing key aspects in geological history of the sedimentary cover and hydrocarbon potential formation. In conjunction of structural interpretation for each structural and tectonic unit of the region, the most promising hydrocarbon bearing sequences were specified. The created geological model of the northern Barents Sea reflects structure patterns of basement and hydrocarbon bearing sequences of the sedimentary cover and it allows conducting a sound geological oil and gas zonation, cost estimate of mineral resources for government regulation of subsoil management relations as final products of regional geological-geophysical studies. Before beginning targeted regional geological exploration works, the northern Barents hydrocarbon potential was estimated at the level of initial total in place resources, i.e., a quantitative estimate was not made even by category D, and a structure potential was confined by one anticlinal structure with the area of 1000 km2. Currently, in the northern Barents Sea, 79 local anticlinal highs have been detected with a total area of 42000 km2. Wide areas of non-structural trap development with a total area of 30000 km2 have been recognized. The obtained quantitative estimate of the anticipated raw hydrocarbons shows multi ordinal growth of the mineral resources value in the studied region and their attractiveness for subsoil users. Presently, all the northern part of the Barents Sea has been divided into licensed blocks purchased by subsoil users or being at the stage of licensing.
Khalid Altayeb
Petroleum Exploration and Production Research Institute of Sinopec, China
Title: Seismic interpretation and structural identification of Iroko-Mokoko-Abana fields, offshore Cameroon
Biography:
Khalid Altayeb has graduated with a 2nd class (Honors) degree in Geology in 2006 and worked for two years as a part-time Teaching Assistant in the University of Khartoum-Sudan. He had worked for one year as a Geoscience Engineer in China National Logging Corporation (CNLC-Sudan Branch), and then he went to China in 2009 and completed his MSc in Petroleum Geology from the Faculty of Earth Resources of China University of Geosciences, Wuhan, China. Since 2012, he is working as a full-time Research Engineer (Geophysicist and Geologist) in Addax Research Department (ARDP) of Sinopec Exploration and Production research Institute (PEPRIS), Beijing, China.
Abstract:
The Iroko-Mokoko-Abana fields (hereto referred as IMA) are located in the Rio-Del Rey’s basin of the Niger Delta within an area of 24,108 acres (97.56 square kilometers); in which oil and gas accumulations are associated with multiple stacked structural traps formed in response to shale diapiric activity and the formation of shale ridges in a deltaic environment, forming a highly structured and complex hydrocarbon traps environment. The structural style of these fields was identified using 3D seismic volume interpretation, where the seismic was combined with wells data. The structural interpretation of six key seismic cross well sections were firstly done to confirm the structural and sedimentary framework, then three key regional horizons of different depth levels were interpreted with their seismic attributes been extracted, and finally the depth conversion of the interpreted time maps were converted using a 2nd polynomial T-D function derived from well information. The integrated results demonstrate that there are 13 big Syn-sedimentary growth faults related to four shale diapirs of the Akata shale formation; these diapirs and their growth faults have acted as a positive element to produce faulted structures and have divided the IMA into 13 micro-faulted-structural blocks. Many additional potential hydrocarbon accumulations are located within these faulted structural blocks.
Khalid Altayeb
Petroleum Exploration and Production Research Institute of Sinopec, China
Title: Seismic interpretation and structural identification of Iroko-Mokoko-Abana fields, offshore Cameroon
Biography:
Khalid Altayeb has graduated with a 2nd class (Honors) degree in Geology in 2006 and worked for two years as a part-time Teaching Assistant in the University of Khartoum-Sudan. He had worked for one year as a Geoscience Engineer in China National Logging Corporation (CNLC-Sudan Branch), and then he went to China in 2009 and completed his MSc in Petroleum Geology from the Faculty of Earth Resources of China University of Geosciences, Wuhan, China. Since 2012, he is working as a full-time Research Engineer (Geophysicist and Geologist) in Addax Research Department (ARDP) of Sinopec Exploration and Production research Institute (PEPRIS), Beijing, China.
Abstract:
The Iroko-Mokoko-Abana fields (hereto referred as IMA) are located in the Rio-Del Rey’s basin of the Niger Delta within an area of 24,108 acres (97.56 square kilometers); in which oil and gas accumulations are associated with multiple stacked structural traps formed in response to shale diapiric activity and the formation of shale ridges in a deltaic environment, forming a highly structured and complex hydrocarbon traps environment. The structural style of these fields was identified using 3D seismic volume interpretation, where the seismic was combined with wells data. The structural interpretation of six key seismic cross well sections were firstly done to confirm the structural and sedimentary framework, then three key regional horizons of different depth levels were interpreted with their seismic attributes been extracted, and finally the depth conversion of the interpreted time maps were converted using a 2nd polynomial T-D function derived from well information. The integrated results demonstrate that there are 13 big Syn-sedimentary growth faults related to four shale diapirs of the Akata shale formation; these diapirs and their growth faults have acted as a positive element to produce faulted structures and have divided the IMA into 13 micro-faulted-structural blocks. Many additional potential hydrocarbon accumulations are located within these faulted structural blocks.