2^nd World Congress on Petroleum and Refinery June 1-3 , 2017 Osaka, Japan

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.

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.

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.

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.    

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.

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.

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.

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.

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.

Biography:

Sun Renyuan is a Professor of Petroleum Engineering in the School of Petroleum Engineering, China University of Petroleum (East China). His research includes unconventional oil and gas development, enhanced oil and gas recovery.

Abstract:

On the basis of the characteristics of thin layers, low reservoir temperature and super heavy oil of Block X of CF oilfield in China, a new technology of HDNS (including Horizontal well, viscosity Depressant, Nitrogen and Steam) was proposed and a series of experiments were conducted to analyze the mechanisms of HDNS. The self-designed equipment, which includes the steam generation system, gas injection system, chemical injection system, the sand-parking sample system, the temperature-controlled system, the metering system of produced fluids and the data collecting system, was used for the simulation. Experiments shows that the displacement efficiency increases with the increase of the steam temperature and the injecting rate of steam, but too high steam injection rate will decrease the displacement efficiency because of steam channeling. Compared with steam huff and puff the displacement efficiency of viscosity depressant assisted steam (DS), increases about 20% because of the thermal chemical effect. The viscosity depressant, N₂ assisted steam huff and puff (DNS) can increase the displacement efficiency in about 18% by using the synergistic effects of viscosity depressant, N₂ and steam. In the process of DNS stimulation, the viscosity depressant can reduce the viscosity of super heavy oil combined with the effect of steam, which is called as thermal chemical effect. The N₂ can prevent the steam channeling in the reservoir and decrease the heat loss in the process of steam stimulation. The DNS stimulation can effectively reduce the oil viscosity and the steam injection pressure, expand the steam sweep efficiency. By using this technology, Block X of CF oilfield has been successfully developed in these years.

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:

In this paper, we focus on the geological storage of CO₂ in reservoirs with zones that are cold enough to facilitate CO₂ hydrate formation at local pressures. A 2D hydro-chemical mechanical model which has five layers (three layers with aquifers and two layers with cap rock in which we introduced two fractures) is created. We apply a reactive transport reservoir simulator, RetrasoCodeBright (RCB), in which hydrate is treated as a pseudo mineral. Following the recent modifications to account for hydrate dynamics in the code through a kinetic approach, we have further improved the simulator to implement the non-equilibrium thermodynamic calculations. In the present study, we spot the light on the hydrate formation effects on porosity in different regions, as well as on the flow pattern. These simulations are based on classical relationships between porosity and permeability, but the outline of ongoing modifications is presented as well. A critical question in such systems is whether hydrate formation can contribute to stabilizing the storage, given that hydrates are pore filling and cannot be stable toward mineral surfaces. The implications of hydrate formation on the geo-mechanical properties of the model reservoir are other aspects addressed in this study. This is an ongoing study with a constant development of adding new phase transitions involving hydrate into the simulator. Hydrate formation from aqueous solutions of hydrate formers is the most recent addition. Hydrate formation from primary or secondary adsorption on minerals is in progress. The overall goals is a hydrate simulator that can imitate real production scenarios (pressure reduction, temperature change, CO₂ injection) but also become a tool for estimating leakage fluxed of methane due to contact between hydrate and ground water under saturated with methane.

Biography:

Shigeru Yao is a Doctor of Engineering, currently working as a Professor of Department of Chemical Engineering, Fukuoka University. He has obtained his Engineering Doctor’s degree at Kyoto University. Currently, his research focus is on self-organization mechanism of polymer and especially the crystalline supramolecular interaction between side chain crystalline block co-polymer and crystalline polymer. He also focuses on the material recycle of polymers.

Abstract:

A block co-polymer constructed with two monomers: a monomer with a long alkane side-chain (more than 10 carbon atoms) and another monomer with various function (such as solvent affinity), shows side-chain crystallization (Side Chain Crystalline Block Co-polymer:SCCBC). Recently, we had found that the SCCBC has an adsorption function to polyethylene (PE) crystal and can modify the surface property of PE chemically and easily. By using this function, SCCBC can be a good dispersant for PE particle dispersion. Dispersant mechanism by SCCBC shows adsorption function caused by the construction of pseudo crystal between macromolecules of PE surface and long alkyl side chains of SCCBC. This interaction is called as crystalline supramolecular interaction. The wax is considered to be a low molecular weight PE. In this study, we found that the crystal structure of wax was influenced by SCCBC. Moreover, a concentrated wax/oil mixture was not solidified with a small amount of SCCBC. This result means that the SCCBC can be a good wax dispersant.

Biography:

Yuri Galant graduated from Baku State University, as Engineer - Geologist in Prospecting and Exploration of Mineral Resources. He then defended thesis on, “Natural gases southern slope of the Greater Caucasus and gas geochemical prospecting of sulfide ores”. In Baku, at Institute of Geology of Azerbaijan National Academy of Sciences, he did research on the degassing of the Earth, fluids of Kola ultradeep well and Saatli ultradeep well and on the development of gas-geochemical methods to search for polymetallic deposits. Degassing of the Earth is the basis for modeling the formation of oil and earthquake prediction. Oil Geneses is his favorite theme/scientific base as this is data of unique KOLA super deep well, (12600 m) and SAATLY super deep well, (8267 m). His other research interests are study and research of fluids/gas in different geological objects: Oil, ore, seepages, underground and mines water, mines air, soil, etc., and the different geological objects - genetic type of rocks, different ages from Q to Arz, in different structure: Rifts, platforms, faults, volcanoes and different depth from surface to ultradepth upto 12600 m. Now, he is building a model of the formation of petroleum, from the Big Bang to modern days. And also he tries to consider building a model of the formation of crude oil on the basis of magmatic aspects.

Abstract:

The issue of hydrocarbon sources to form the deposits of oil fields remains relevant, despite the long history of its study. Scientific advanced techniques in this case are the results of a study of unique ultra-deep wells. The greatest interests are SG-3 Kola which is unique and the deepest one in the world with 12262 meters and SG-1 Saatli with 8268 meters. Kola super-well has been drilled on the ancient Baltic shield and opposite to Saatli, which has been drilled on the young Kura rift structure. Thus, there is a unique opportunity to trace hydrocarbon saturation of ultradepth in the time interval from the ancient Archean rock to the present day. Hydrocarbon in SG1Saatly and the SG-3 Kola are in different forms like: Free, dissolved, adsorbed and occlude. In the Kola segment of the Baltic Shield abundantly distributed C1-C7 alkanes, and bitumen were there. The content of the gases in the microcracks of rocks is upto 55.8 liter / ton and bitumen up to 110 grams / ton. In closed rock pores and vacuoles methane content is in the range 0.04 -120.1 cm3 / kg. In the Saatli well, the composition of gases presented to C5, inclusive, and hydrocarbon gas saturation is up to 5.7 cm 3 / kg. In its composition, rocks gases unique ultradeep wells resemble the composition of oil and gas fields. Hydrocarbons of different forms and components exist along the whole section of Kola and Saatli. Thus, the combined section of diverse genetic groups of rocks and various types of geological structures like Kola (shield) and Saatli (geosyncline) showed that in ultradepth the temporary crustal section from the Archean 3 billion years and till today there are hydrocarbon gases. Thus ultradepth saturated hydrocarbons virtually exist from the early Archean geological history and up to modern times of the Earth and can be a source of oil and gas fields. Oil Geneses is my favorite theme. Scientific base for this is data of unique Kola Super deep well, (12600 m) and Saatli Super deep well, (8267 m). Studying and researching of fluids/gas in the different geological objects like: Oil, ore, seepages, underground and mines water, mines air, soil, etc., and the different geological objects, genetic type of rocks, different ages from Q to AR, in the different structures like: Rifts, platforms, faults, volcanoes and different depth from surface to ultra depth of 12 600 meter. It is allowed to create a new polygenic model for the formation of oil fields. This model offers perspectives of the search for new deposits in geological heterogeneous objects. On the basis of this model, it is expected to develop a new strategy of finding oil deposits.

Biography:

Phuti Cedric Tsipa is currently a Master’s student in the Centre for Rubber Science & Technology at the Nelson Mandela Metropolitan University (NMMU). He has completed his Bachelor’s degree in Chemistry and Polymer Science at the University of Stellenbosch and moved to NMMU for Post-graduate studies in Physical and Polymer Science. His research interest in this field was sparked during his honour’s year when he developed a method to extract processing oil used in the production of tyres. He subsequently developed a chemical degradation method for waste tyres to produce potentially reusable char and oil.

Abstract:

Tyre dumps are a growing problem around the world due to the challenges faced in the disposal of tyres. The complex nature of a tyre makes it resistant to biological degradation and difficult to dissolve or melt. One of the common processes in which waste tyres are recycled is pyrolysis. Although this method has been under research for many years, its products still have low market value. This study proposes a chemical degradation method as an indirect alternative to pyrolysis and attempts to produce valuable products. Characterization methods that were carried out on the oil were GC-MS and SIMDIST ASTM D86 for better understanding of the composition and petroleum fractions of the oil. The results showed that foreign compounds were present in the extracted oil compared to commercial oils. The bulk of the petroleum fractions of the oils were light vacuum gas oil 343-455 ^oC followed by heavy vacuum gas oil 455-566 ^oC. These findings indicate that oil produced by this method falls in the category of heavy oils, which can potentially be hydrocracked using a suitable catalyst to produce useful petroleum products.

Biography:

Abstract:

Crude oil recovery technologies were unable to meet the growing energy demand in China. Microbial Enhanced Oil Recovery (MEOR) was one of the most effective recovery methods for the oil fields. Biosurfactant in oil degradation and emulsification changed the solid oil into liquid oil to be exploited. This was the most important mechanism of MEOR technology, but because of the complex geological conditions of different oil reservoir types, the microorganisms used in petroleum recovery lack enough environmental adaptability. Several high environmental adaptive capacity microfloras were screened, which withstand high temperature (30-80°C), salinity (NaCl concentration of 5-20%, w/v) and pH (5-9). Produced biosurfactant withstand 10-90°C, pH 5-12, NaCl concentration 1-20% (w/v). Further fermentation process optimization was carried out, and the active metabolites including bioemulsifiers, biosurfactants, acids and alcohol showed good potential for application. This can greatly improve the oil remaining after waterflood recovery from 11.55% to 30.78% by physical model. A variety of active microfloras which form a complex system can reduce the surface tension, improve emulsifying activity and emulsion stability. The surface tension (less than 30 mN/m) and emulsifying activity (more than 60%) were maintained at a strong level, better emulsification activity for crude oil can be maintained for more than 120 h, which showed potential industrial application. The composite microbial oil displacement agent with nutrients and trace elements has been injected into the oil well in Changqing Oilfield. Results showed that oil production of the low yielding well (0.2 T/day) was improved more than 3 times, the produced liquid water content decreased by more than 75%, from 85% reduced to 25%, oil recovery is improved by 5-8 times, from 0.15 T/d to 0.9 T/d. 

Biography:

Asif Mehmood has been doing PhD in Petroleum Engineering at China University of Petroleum (East china). His major is Reservoir Engineering.

Abstract:

In Pakistan, about 1000 oil and gas exploratory wells have been drilled having depth ranging from 230 m to +6400 m. More than 60 percent wells have been abandoned or dry wells. In spite of all exploratory efforts, the energy need of the country is not being overcome. Present study looks forward to reutilize these abandoned wells by using subsurface data related to thermal characteristics of rock sequence. Present study shows heartening geothermal gradient exception in lower Indus Basin coupled with buried fossil-fail-rift basement structure. Aeromagnetic survey has also disclosed significant prediction for the “hot dry rock” geothermal energy in Kharan-Panjgur tectonic depression in western part of the Pakistan. Literature review shows that, for electricity production, hot dry rock (HDR) geothermal environment offers massive potential. These resources are mostly much deeper than the hydrothermal resources. Hot dry rock energy comes from moderately water-free hot rock found at a depth of 4,000 meters or more below the earth surface. In contrast to a geothermal field in one of the tectonic/volcanic anomalies, the HDR system depends on the artificial simulation of tight formations by hydraulic fracturing to create underground heat exchanger. Fluid is circulated in closed circuit mode whereas reservoir pressure is managed by balanced production and injection rates in multiple well arrays. Current study shows the matchless application of collection data of oil and gas exploratory wells to develop renewable and sustainable energy operation in Pakistan.

Biography:

Muhammad Rivaldi Anwar Putra is currently pursuing his undergraduate studies in Universitas Gadjah Mada, Indonesia. He is the Member of American Association of Petroleum Geologist – Student Chapter in Universitas Gadjah Mada, Indonesia.

Abstract:

The zone which has a high resistivity value is identical to the hydrocarbon bearing zones, however zones with low resistivity tend to be ignored as a hydrocarbon zones. In fact, at some oil and gas fields in several countries such as Indonesia, China and America showed that hydrocarbon zones can be formed in the zones with low resistivity. Therefore, this study aimed to evaluate the hydrocarbon zones with low resistivity in wells "A", at the field "X" between depths of 5514-5523 feet MD. Log data and core data are used in this study whereas the research is conducted by qualitative and quantitative analysis. The qualitative analysis used to determine lithology, facies and depositional environment of rocks in wells "A". The quantitative analysis used to determine the distribution of shale which is considered as a major influence on the formation of hydrocarbon bearing zones with low resistivity by using the Thomas-Stieber equation, calculation of porosity associated with the resulting distribution of shale and calculation of water saturation of the wells concerned using the Simandoux and Indonesia equation which is then compared with the Archie equation or core data. Quantitative analysis showed a significant result where at resistivity average of 5.8 ohm.m, the porosity has an average value of 17% and water saturation has an average value of 55.6%.

Biography:

Szymon Kuczynski is currently working as a Research Assistant in Natural Gas Engineering Department. His research interests are related to fluid mechanics, natural gas composition analysis, real time in situ monitoring systems, energy sources and mathematical models.

Abstract:

With currently observed increase of the demand of hydrogen, new ventures and projects are conducted to deal with certain stages of generation of this chemical element. Hydrogen has numerous advantages in various industries. The most crucial one is the wide range of production techniques using several resources, making it more applicable as compared to other chemical elements. The other advantage is its environmental friendly application as an energy source. This issue may make considerable change in automotive industry in the nearest future. With certain number of advantages, a few disadvantages are observed. The most essential problem is associated with lack of necessary facilities: Mass production units, transportation grids and storage systems. The last point could be solved with salt caverns and depleted oil and gas reservoirs, as they offer large deposit quantities and impermeable interior to keep the hydrogen inside. Complex examination of this part would simplify and intensify the technical studies regarding the hydrogen usage. Paper investigates the economic influence of particular parameters of hydrogen storage in salt caverns. The initial point of the research is the stage of leaching the cavern to enable the storage with any relevant machinery. The following cavern elements involve completion devices as wellhead and exploitation pipes. Surface technical setup consists of the hydrogen compressing facility, pumping equipment, gas (hydrogen) drying unit, gas reduction and measurement plants. Necessary supporting infrastructures needed to maintain the work: Electric steerable systems, preparation of plant (ground possession, construction of roads and staff base). The economic analysis covers different scenarios with respect to the localization, cavern volume, years of usage of the facility and resources prices. NPV and IRR factors for scenarios are evaluated.

Biography:

Mariusz Laciak is a Professor and Head of Natural Gas department at Drilling, Oil and Gas Faculty at AGH UST. His main research activities are related to natural gas transmission, natural gas production, natural gas energy and utilization.

Abstract:

Mobility is a must of everyday life, which led us to the oil dependence. Global economic changes caused that natural gas is recognized worldwide as the main and leading alternative to oil products in the transportation sector. There is a huge barrier to convince vehicle users to switch to natural gas, the lack of refueling infrastructure for natural gas vehicles (NGV) is frequently the case. The key to solve this problem is to provide a refueling infrastructure solution for natural gas vehicles, fast refueling units ready to work in household condition. Home fast refueling units operate with natural gas (methane), which is being provided through gas pipeline grid and become the largest vehicle refueling infrastructure. Home fast refueling units and NGV owners will enjoy day-to-day time savings and convenience: Home car refueling in minutes, month-to-month fuel cost economy, year-to-year incentives and tax deductibles on natural gas refueling system as per country, reduce CO₂ local emissions, saving costs and money. The procedures of the final production prototype, independent of operational performance and accounting for the safety issues have been tested and described in the paper. The aim of the safety tests is to test externally and independently analyze HRS production prototypes for safety aspects. The test simulated various scenarios and operational conditions and situations and was analyzed to show how current production prototype responds to various simulations. The operational performance tests were dedicated to external independent testing of HRS production prototypes for operational performance. The main tested parameters were productivity m³/h, energy consumption kW/h, the speed (rate) of refueling is hour or min.

Biography:

Tomasz Wlodek is currently working as a Research Assistant in Natural Gas Engineering Department. His main research interests are related to LNG technology, pipeline transmission of natural gas, hydrogen and CO₂ and natural gas composition analysis.

Abstract:

Energy storage methods may be used for covering energy demand fluctuations and for integration power generation from renewable energy sources as wind plants and solar farms. Classic form of energy storage is hydropower energy storage in top-pumped power plants. Other possibilities of energy storage as alternatives for classic solutions are compressed air or hydrogen energy storage in appropriate geological conditions. Salt caverns are the most relevant formations for hydrogen and compressed air energy storage. The possibilities of hydrogen energy storage application in Polish conditions are presented in this paper. In Poland, there are many suitable geological formations for salt caverns construction, especially in northern and north-western part of the country. Also in northern and western part of Poland, there are the most suitable wind conditions for wind farm localization. The location of large industrial plants (e.g., oil refineries in Gdansk and Plock), which need hydrogen for their technological processes, is also very important factor. In this case the salt caverns may be hydrogen storage for industrial purposes besides the energy storage. This situation requires the design of all infrastructures for transportation and utilization of hydrogen. Hydrogen may be transported in especially designed high pressure pipelines. Pipeline transport of hydrogen is quite similar to natural gas transport. Physical properties of hydrogen cause lower pressure drops along the pipeline. One of methods of hydrogen utilization is to add it to natural gas pipeline system for improvement of natural gas transportation parameters. Hydrogen transportation and storage processes causes’ material challenges because of the hydrogen potential to penetrate the crystal lattice of steel leading to hydrogen corrosion. In this paper underground hydrogen storage methods and design aspects of salt caverns and infrastructure challenges are considered. It is concluded that there are possibilities for effective hydrogen energy storage in Poland.

Biography:

Qunming Liu is currently a Reservoir Engineer in Research Institute of Petroleum Exploration ＆Development, CNPC. He received Master’s degree in Petroleum Geology from China University of Geosciences (2009) and PhD in Petroleum Development Engineering from the Research Institute of Petroleum Exploration ＆ Development (2012). His main research interests are natural gas development geology and tight gas development. 

Abstract:

With continuously deeper development of "Sulige" Gas Field, which is domestic typical representative of Tight Gas Sand, its development pattern has already changed from single vertical well development to multiple well-type development including vertical, cluster and horizontal well. How to optimize Well Spacing of multiple well type under complicated geological conditions is one of key technique problems for enhancing recovery rate of gas field. Based on the fine geological a anatomy of dense well pattern test area using reservoir architectural analysis method, large-scale composite sand body of braided river is divided into 4-grade architectural elements, which is braided river system, composite channel sand body, single channel and point bar and optimizing well spacing technique targeting composite channel sand body, the second grade architectural elements, has formed. According to the differences of interior reservoir structure characteristic, three lithofacies types of the second grade architectural elements, which is superposition belt, transitional belt and inter-system belt is identified, and ancient landform controls the distribution of different lithofacies types. Reservoir pattern determine development well type: superposition belt suitable for the integral development of horizontal well, transitional belt suitable for the cluster well development, and inter-system belt suitable for the vertical well development of sweet spot, and quantitative recognition standard of various lithofacies has been established. The field application of such technique showed satisfactory results, 63 horizontal wells, 9 cluster well groups consisting of 5~7 wells, and 12 vertical wells, have been deployed, and numerical simulation result shows recovery rate of gas field is enhanced a lot due to mixed well type development especially horizontal well development. Research results instructed the next development of Sulige Gas Field, and provide reference for domestic gas reservoir of such type.

Biography:

Cheng Lihua is a Senior Gas Development Engineer. He has received his PhD in Petroleum Geology from China University of Petroleum in 2006. He has worked in Research Institute of Petroleum Exploration and Development. For the past 10 years, he has been engaged in the research of reservoir characterization, tight gas development, carbonate gas development, and basement rock gas development. He has published more than ten articles and one book about oil and gas development.

Abstract:

So far, oil reservoirs account for most of the basement reservoirs which are developed. Basement gas reservoirs are relatively rare and most of them are developed for a short period. The Dongping gasfield of the Qaidam basin is a typical basement reservoir, which were developed in 2013. It is very meaningful to study on the development characteristics of basement gas reservoirs in depth. The thick basement rocks are usually old blocks which have endured a very long period of uplifting, exposure and weathering. There are mainly two types of reservoir spaces in basement rocks. One of them is the zone of dissolved pores and caves, which is commonly a thin zone with relatively good porosity. The other is the fracture belt, which is a relatively thick and less porous belt formed by the mechanism of tectonic movement, surface water dissolution or/and underground water dissolution. These two types of reservoir spaces make the basement rocks a typical dual-porosity reservoir. Basement reservoirs are always characterized with low porosity and relatively high permeability. The tested productivities of basement reservoirs are very high. Some wells may show open-flow capacities more than a million m3/d. The high tested productivities may be caused by high connectivity of basement reservoirs, which makes it much easier for gas to flow in a large area. Another characteristic of basement reservoir is their high single well production rate and their capacities for stable production. Their production indexes are in the range of maximum production capacity. This is depended on the controlling of producing rate and the preventing of bottom water coning. Comparing to conventional gas reservoirs, basement reservoirs show some unique features, which are their block shape, high reservoir connectivity, bottom water and high single well producing rate. Development of basement reservoirs should pay full attention to those unique characteristics. Development strategy should be based on the view of the whole reservoir and well pattern should be optimized to yield a high production rate.

Biography:

Gao Xiaolong is a Master’s student whose research focuses on the purification and structure analysis of bioemulsifier, and environmental remediation of petroleum hydrocarbon pollution, especially towards the heavy crude oil polluted soil and water.

Abstract:

The bioemulsifier was secreted by strain Geobacillus pallidus XS2-450 which was obtained based on atmospheric and room temperature plasma (ARTP) mutation of XS2, isolated from oil-contaminated soil in the Yumen oilfield, China. The bioemulsifier was extracted, purified and characterized, and its emulsifying properties were evaluated. The purified bioemulsifier showed high emulsifying activity (E24%=83%) on xylene. The chemical characterization of the bioemulsifer was performed using HPLC/MS/MS and GC/MS. It was found to contain 76.2% of carbohydrates, consisting mainly of galactose mannose rhamnose and glucose, 7.3% proteins with a 60 KDa active component and 16.5% of lipids. The results suggest that the bioemulsifier was a glycolipids-protein complex. Furthermore, the composite microbial communities major including bioemulsifer, biosurfactants and other active metabolites coupled with nutrients and trace elements were used to deal with sludge samples, the oil content of the oily sludge samples decreased from 6.1% to 0.8%. These data illustrated that the bioemulsifier performed a high potential in applications and had important economic values.

Biography:

Wang Xingbiao has his expertise in microbial degradation of petroleum hydrocarbon and metabolites analysis. His open and contextual evaluation model is based on mechanism of hydrocarbon degradation and metabolism. After years of experience in research, application, administration both in laboratory and oil well and oil polluted sites. His main work focused on microbial enhanced oil recovery and crude oil pollution management, and has improved the oil recovery more than 4 oil wells, increased 200 tons of oil extraction. Cumulatively, another important application work was reducing heavy oil in soil from 21.0% to 0.2% (w/w) in the oily sludge treatment, and the annual output value was more than 3 million US dollars in 3 oilfields of China. 

Abstract:

Crude oil recovery technologies were unable to meet the growing energy demand in China. Microbial Enhanced Oil Recovery (MEOR) was one of the most effective recovery methods for the oil fields. Biosurfactant in oil degradation and emulsification changed the solid oil into liquid oil to be exploited. This was the most important mechanism of MEOR technology, but because of the complex geological conditions of different oil reservoir types, the microorganisms used in petroleum recovery lack enough environmental adaptability. Several high environmental adaptive capacity microfloras were screened, which withstand high temperature (30-80°C), salinity (NaCl concentration of 5-20%, w/v) and pH (5-9). Produced biosurfactant withstand 10-90°C, pH 5-12, NaCl concentration 1-20% (w/v). Further fermentation process optimization was carried out, and the active metabolites including bioemulsifiers, biosurfactants, acids and alcohol showed good potential for application. This can greatly improve the oil remaining after waterflood recovery from 11.55% to 30.78% by physical model. A variety of active microfloras which form a complex system can reduce the surface tension, improve emulsifying activity and emulsion stability. The surface tension (less than 30 mN/m) and emulsifying activity (more than 60%) were maintained at a strong level, better emulsification activity for crude oil can be maintained for more than 120 h, which showed potential industrial application. The composite microbial oil displacement agent with nutrients and trace elements has been injected into the oil well in Changqing Oilfield. Results showed that oil production of the low yielding well (0.2 T/day) was improved more than 3 times, the produced liquid water content decreased by more than 75%, from 85% reduced to 25%, oil recovery is improved by 5-8 times, from 0.15 T/d to 0.9 T/d. 

Biography:

Sergey K Sokhoshko has defended his PhD thesis at the Tyumen State Oil and Gas University (Russian Federation). Currently, he is a Professor of the Department of Oil and Gas Fields Development and Production. He specializes in modeling of oil and gas wells with complex trajectories, as well as hydraulic fracturing.

Abstract:

Statement of the Problem: Presently when drilling horizontal wells the length of a wellbore traced through the producing formation can stretch many hundreds of meters. In order to calculate productivity of such well and its separate intervals it is very important to know the fluid to the wellbore inflow profile, inflow rate along the wellbore as well as pressure drop along the wellbore. The objective of this study is to obtain a technical solution and to develop a calculation technique which would allow calculation of the above operation parameters for steady state of both oil and gas wells with complex trajectories.

Methodology & Theoretical Orientation: The point source method was used to simulate perforations in the wellbores of both oil and gas wells in order to calculate the mode of operation of a complex trajectory well. A calculation result for a fixed flow point source in a formation with impermeable top and bottom and available external reservoir boundary (injection wells) was obtained using results of calculations of the fixed flow point sources in an infinite formation in addition to the infinite imaging method relative to the top and bottom of formation.

Findings: Productivity of a complex trajectory well as well as the profile of fluid movement to the wellbore depend on the well trajectory, type of bottom hole completion and producing formation parameters, which have to be taken into account both in well planning as well as in field development design stages.

Conclusion & Significance: The designed technique allows to calculate the productivity in complex trajectory wells and in its separate intervals, pressure drop in the wellbore, increases in the oil and gas flow rates, as well as to calculate an optimum length of horizontal section of the wellbore and its trajectory through the producing formation.

Biography:

Muhammed A Ismail graduated from Baghdad University, Faculty of Engineering, Petroleum Engineering Department in 2006, June. In September 2007, he successfully passed the Turkish examination conducted in Kirkuk and got eligibility to study Master's in Republic of Turkey. In 2007, he started in Gazi University in Turkey, Ankara, Training and Education Center (Tomer). I participated successfully TCS exam in 2008, July and got study in Istanbul University. In 14-Oct-2008 registered in Istanbul University Faculty of Engineering Geological Engineering Department. In 18-Aug-2011 graduated from this school and got a master's degree. In 2011, September I started working as a teaching in Kirkuk University. In 2013, October I got a scholarship to study for a doctorate PhD in Azerbaijan, Baku. Know I’m studying in Khazar University Faculty of Engineering and Applied Science, Petroleum and Gas Engineering department.

Abstract:

The main aim of this research is to determine nearest and acceptable predicted permeability value obtained from wire line logs compared with those values coming from core sample analysis within two wells belonging to two domes from small giant Bai Hassan oil field, using irreducible water saturation graph method. This work consists of three main parts: Part one is well logs analysis, which involves determination of Archie petrophysical parameters, porosity corrected from volume of shale, water saturation and irreducible water saturation. The second part is predicting permeability using irreducible water saturation from well log analysis and comparing the estimated values with the data of permeability that measured from core sample in BH-20 and BH-53 well. The last part was using SPSS statistic software to determine the factor that can give the very nearest and acceptable values, these values uses to estimate real permeability for another wells distributed on each dome of the small giant Bai Hassan oil field. Excellent correlation obtained (R²=0.978 in BH-20 and R²=0.9945 in BH-53) between estimated permeability values based on irreducible water saturation and permeability that got from core sample. The result of statistical method (SPSS software) is:

K _Core = (K _Predicted*1.040)-3.363 (BH-20) [Kithka Dome]

K _Core = (K _Predicted*1.030)-3.359 (BH-53) [Daoud Dome]