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1
VYZHVA, Sergiy, Ihor SOLOVYOV, Ihor МYKHALEVYCH, Viktoriia KRUHLYK, and Georgiy LISNY. "APPLICATION OF DIRECT HYDROCARBON INDICATORS FOR OIL AND GAS PROSPECTING IN THE DNIPRO-DONETS DEPRESSION." Ukrainian Geologist, no. 1-2(44-45) (June 30, 2021): 99–108. http://dx.doi.org/10.53087/ug.2021.1-2(44-45).238953.
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Based on the results of numerous seismic studies carried out in the areas and fields of the Dnipro-Donets depression, the strategy to identify hydrocarbon traps in this region has been developed taking into account modern requirements for prospecting and exploration of gas and oil fields. The studies are designed to determine the favorable zones of hydrocarbon accumulations based on the analysis of the structural-tectonic model. A necessary element for solving such a problem is to aaply direct indicators of hydrocarbons to predict traps of the structural, lithological or combined type. It was determined that an effective approach to identify hydrocarbon traps in the region is attribute analysis employing seismic attributes such as seismic envelope, acoustic impedance or relative acoustic impedance. In most cases of practical importance, the analysis of the distribution of the values of these attributes turned out to be sufficient for performing the geological tasks. It is given an example of extracting additional useful information on the spatial distribution of hydrocarbon traps from volumetric images obtained from seismograms of common sources with a limited range of ray angles inclinations. To analyze the distributions of seismic attribute values, it is recommended to use the Geobody technology for detecting geological bodies as the most effective when using volumetric seismic data. The distributions of various properties of rocks, including zones of increased porosity or zones of presence of hydrocarbons are determined depending on the types of seismic attributes used in the analysis,. The use of several seismic attributes makes it possible to identify geological bodies saturated with hydrocarbons with increased porosity and the like. The paper provides examples of hydrocarbon traps recognition in the areas and fields of the Dnipro-Donets depression practically proved by wells. A generalization on the distribution of promising hydrocarbon areas on the Northern flank of the Dnipro-Donets depression and the relationship of this distribution with the identified structural elements of the geological subsoil is made.
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Vyzhva, S., I. Solovyov, I. Mihalevich, V. Kruhlyk, and G. Lisny. "USE OF QUANTITATIVE DATA OF 3D SEISMIC EXPLORATION FOR DETECTION OF TRAPS OF HYDROCARBONS WITH IN THE NORTH SIDE OF THE DNIEPER-DONETSK DEPRESSION." Visnyk of Taras Shevchenko National University of Kyiv. Geology, no. 4 (91) (2020): 35–41. http://dx.doi.org/10.17721/1728-2713.91.05.
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Based on the results of numerous seismic surveys conducted on the areas and deposits of the northern side of the Dnieper-Donetsk depression, an appropriate strategy for detecting hydrocarbon traps in this region has been determined. This takes into account modern requirements for exploration and prospecting of gas and oil deposits. They consist in determining the probable zones of accumulation of hydrocarbons based on the analysis of the structural-tectonic model. At the same time, the use of direct hydrocarbon indicators to predict structural, lithological or combined traps is also a necessary element in solving this problem. It has been shown that an effective approach to detecting hydrocarbon traps in this region is attribute analysis using seismic attributes such as seismic signal envelope, acoustic impedance or relative acoustic impedance. In most practically important cases, the analysis of the distribution of values of these attributes was sufficient to solve geological problems. At the same time, an example of extracting additional useful information on the spatial distribution of hydrocarbon traps from volumetric seismic images obtained from seismograms of common sources with a limited range of seismic angle inclinations is given. To analyze the distributions of seismic attribute values it is recommended to use geobody technology as the most effective one when using volumetric seismic data. Depending on the combination of seismic attributes involved in the analysis, the distributions of different properties of rocks are determined, in particular the zone of increased porosity or the presence of hydrocarbons. Analysis with the simultaneous use of several seismic attributes allows to directly identify hydrocarbon-rich geological bodies with high porosity and the like. The paper presents examples of detection of hydrocarbon traps in the areas and deposits of the northern side of the Dnieper-Donetsk depression, which are confirmed by drilled wells. An example of providing recommendations for wells drilling using the distributions of values of different seismic attributes is given. Generalizations are made on the distribution of promising areas for the presence of hydrocarbons on the northern side of the Dnieper-Donetsk depression and the ratio of this distribution with the identified structural elements of the geological environment.
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Leonov, M. G., V. Yu Kerimov, R. N. Mustaev, and Vu Nam Hai. "ON THE NATURE AND MECHANISM OF FORMATION OF HYDROCARBON DEPOSITS ON THE SHELF OF VIETNAM." Tikhookeanskaya Geologiya 39, no. 5 (2020): 3–16. http://dx.doi.org/10.30911/0207-4028-2020-39-5-3-16.
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The paper presents the results of the study of main factors determining conditions of formation and distribution of oil and gas deposits within the Cenozoic sedimentary cover and Precenozoic granite basement of the Vietnam shelf. The structural and tectonic model of the Kyulong basin constructed by the authors allows to reveal the conditions of formation of regional and local structures in the sedimentary cover containing hydrocarbon deposits; mechanisms of hydrocarbon traps emergence and hollow space (collectors); genesis of hydrocarbons, including the hydrocarbons existed in the basement rocks; the possible mechanism of migration and accumulation of hydrocarbons in the basement rocks. The traps which are real or potential reservoirs of hydrocarbons in the body of a crystal socle are widely developed. The structural and tectonic processes in the basement itself resulted in the development of positive morfostructures (domes, protrusions) the cores of which are made of disintegrated (granulated) rocks of a crystalline cap. In order to reconstruct the chronothermobaric conditions of occurrence and evolution of hydrocarbon generation centers and to restore the conditions of formation and distribution patterns of oil and gas accumulations on the shelf of Vietnam, three-dimensional modeling of generation and accumulation hydrocarbon systems was performed using the basin modeling technology and PetroMod software (Schlumberger, Ltd, USA). Studies of hydrocarbon biomarkers of oil fields in the Kyulong basin, including those located in the crystalline basement have shown the similarity of biomarker parameters of oil and organic matter, which demonstrates the organic nature of the oil fields of the basement on the shelf of Vietnam
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Sharma, Manish, and Michael Shane. "Hydrocarbon-Water Adsorption and Simulation of Catalyzed Hydrocarbon Traps." Catalysis Today 267 (June 2016): 82–92. http://dx.doi.org/10.1016/j.cattod.2016.01.021.
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Nguyen, Chuc Dinh, Xuan Van Tran, Kha Xuan Nguyen, Huy Nhu Tran, and Tan Thanh Mai. "The forming mechanisms of Oligocene combination/stratigraphic traps and their reservoir quality in southeast Cuu Long Basin offshore of Vietnam." Science and Technology Development Journal 22, no. 1 (April 10, 2019): 185–95. http://dx.doi.org/10.32508/stdj.v22i1.1216.
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To date, most of the oil and gas production in Cuu Long Basin (CLB) is contributed from structural traps, making them more and more depleted after years of exploitation. Exploration activities in CLB, therefore, are shifting towards other traps, including stratigraphic and/or combination ones. The results of exploration and appraisal activities in recent years have increasingly discovered more hydrocarbons in the Oligocene section; some of them were discovered in combination/ stratigraphic traps. Many studies on Oligocene targets in Southeast CLB have been carried out but only a few mention nonstructural traps. This leads to uncertainty about the forming mechanisms and distribution, as well as unevaluated hydrocarbon potential of these traps. An integrated approach- utilizing methods of seismic sequence stratigraphy, seismic attribute interpretation, and petrophysical/ petrographical analysis- was applied in this research to identify the forming mechanisms of Oligocene combination/ stratigraphic traps in southeast area of CLB and to evaluate their reservoir quality. The research results show that the key forming factor for stratigraphic traps of sand body is lithology change and the one for pinch-out stratigraphic traps is tapering off of sand layers landward or toward the horsts. The reservoir quality of these traps ranges from moderate to good. By integratedly applying the methods, the forming mechanisms and reservoir quality of Oligocene stratigraphic traps could be delineated. In order to optimize the next-stage exploration strategy in CLB, detailed studies on petroleum system, especially top and bottom seals, and the hydrocarbon potential of these stratigraphic traps, need to be carried out.
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Chen, Guo Min, and Quan Wen Liu. "Essential Model for Oil and Gas Trap Evaluation." Advanced Materials Research 962-965 (June 2014): 626–29. http://dx.doi.org/10.4028/www.scientific.net/amr.962-965.626.
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With the further and high level of hydrocarbon exploration and development in China even around the world, the hydrocarbon exploration tend to be the fine and comprehensive exploration and targets are mainly plays or traps, the structural trap, is the mainly exploration targets, will gradually give way to the alternative exploration objects, the litho-stratigraphic traps, which are more subtle and competitive. Therefore, the new trap evaluation theory model needed to be work out to speed up the hydrocarbon exploration. According to the characteristics of the hydrocarbon traps exploration at present stage, this paper deeply analyzes the trap evaluation contents and characteristics, on the basis of combination with the qualitative and quantitative comprehensive research of trap evaluation parameters, the essential evaluation model is corresponding to traps is established finally.
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Yeon, Tae Hun, Hyun Sik Han, Eun Duck Park, and Jae Eui Yie. "Adsorption and desorption characteristics of hydrocarbons in multi-layered hydrocarbon traps." Microporous and Mesoporous Materials 119, no. 1-3 (March 2009): 349–55. http://dx.doi.org/10.1016/j.micromeso.2008.10.036.
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Czaplewski, Kenneth F., Thomas L. Reitz, Yoo Joong Kim, and Randall Q. Snurr. "One-dimensional zeolites as hydrocarbon traps." Microporous and Mesoporous Materials 56, no. 1 (October 2002): 55–64. http://dx.doi.org/10.1016/s1387-1811(02)00441-9.
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Chen, Guo Min, and Quan Wen Liu. "Comprehensive Evaluation System and Elements for Hydrocarbon Traps." Advanced Materials Research 962-965 (June 2014): 112–16. http://dx.doi.org/10.4028/www.scientific.net/amr.962-965.112.
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The hydrocarbon trap evaluation is theoretical guidance for the practical exploration of hydrocarbon traps, the present complicated exploration targets requires the conclusion of hydrocarbon trap evaluation more scientific and reliable so as to adapt to the requirement of high frequency, high precision trap exploration. With the guidance of system theory and modern scientific evaluation theory, modern hydrocarbon traps evaluation has already become a system engineering, which obviously characterized by the comprehensive evaluation, quantitative evaluation and comprehensive decision. In this paper the comprehensive evaluation system for hydrocarbon traps has been established, it indicated that the comprehensive evaluation tends to be a whole procedure which involves such aspects including evaluation contents, data, methods, techniques, and evaluation process specifically, so its main components includes: evaluation object characteristics, theoretical guidance, evaluation contents, methods, techniques, and database establishment. Furthermore, it emphasize closely on the analysis of the exploration objects, focus on the comprehensive geological research, supported by scientific exploration and thinking and computer technology, considered evaluation method and technology research as the key contents, and finally enable to provide reference for the modern hydrocarbon trap exploration when it appear to become increasingly complicated and subtle.
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Nguyen, Chuc Dinh, Tu Van Nguyen, Hung Quang Nguyen, Cuong Van Bui, Thanh Quoc Truong, and Xuan Van Tran. "Applying seismic stratigraphy analysis for assessing upper Oligocene stratigraphic traps in Southeastern Cuu Long Basin." Science and Technology Development Journal 20, K4 (July 31, 2017): 48–56. http://dx.doi.org/10.32508/stdj.v20ik4.1112.
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As oil and gas production has been going on over a few decades, conventional plays such as pre-Tertiary fractured basement highs and Cenozoic structural traps become more and more exhausted, and the remaining targets of the same type do not have sufficient reserves for development and production. Exploration activities in Cuu Long basin, therefore, are shifting towards more complicating types of plays which are stratigraphic traps and combination traps. Several researches were conducted in southeastern marginal slope and indicated the possibility of stratigraphic pinch-out traps with insufficient petroleum system and low hydrocarbon potential. In spite of many researches, there are still difficulties in defining the distribution and in evaluating hydrocarbon potential of these traps, so seismic stratigraphy analysis in accompanied with interpretation of seismic attribute and well logs is very necessary to support this problem. Seismic stratigraphic analysis on seismic sections, in agreement with seismic attributes’ and log analysis’ findings, show that the stratigraphic/combination traps in Oligocene C and D were formed during lowstand system tract as sigmoid-oblique clinoforms downlapping onto underlying strata in distributary mouths/delta settings. The integration of seismic attribute analysis and well log interpretation has further defined the fan-shaped distribution of these traps. Thus, using various methods, the stratigraphic traps can be better revealed. Further studies, however, need to be carried out to fully evaluate hydrocarbon potential of these stratigraphic/ combination traps, and minimize risks in exploration drilling.
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Luo, Jing, Robert W. McCabe, Mark A. Dearth, and Raymond J. Gorte. "Transient adsorption studies of automotive hydrocarbon traps." AIChE Journal 60, no. 8 (April 25, 2014): 2875–81. http://dx.doi.org/10.1002/aic.14477.
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Chen, Kai, Zhen Liu, and Jun Hui Zhang. "The Application Extension of the Four Key Controlling Factors for the Formation of Lithologic Pool in Hongliuquan Area, Qaidam Basin." Advanced Materials Research 616-618 (December 2012): 441–49. http://dx.doi.org/10.4028/www.scientific.net/amr.616-618.441.
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In order to research the application extension of the viewpoint of the four key factors controlling formation process of lithologic traps, the paper was dissected lithologic reservoir dynamically, mainly analyzing the paleo-fluid dynamics, paleo-hydrocarbon migration pathway, paleo-critical physical properties of reservoirs and paleo-sealing conditions of the traps in formation of hydrocarbon accumulation period. The results show that they recover the limited and most important factors for formation of lithologic traps and come back the formation process of lithologic traps availably, and it also can used to be evaluated low exploration basin dynamically, compositely analyzed key factors controlling formation process of lithologic traps and selected advantaged target area. The application of this methodology indicates that it could be widely used in the dynamic formation of lithologic traps and dynamical evaluation of low exploration basin in Hongliuquan area, Qaidam basin.
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Zelinsky, Ryan, and William S. Epling. "Effects of CO and H2O Co-Feed on the Adsorption and Oxidation Properties of a Pd/BEA Hydrocarbon Trap." Catalysts 11, no. 3 (March 8, 2021): 348. http://dx.doi.org/10.3390/catal11030348.
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Hydrocarbon traps for exhaust emissions control adsorb hydrocarbons in low temperature exhaust and release them as the exhaust warms up. In this work, a Pd/BEA hydrocarbon trap was tested under lean exhaust conditions using ethylene and dodecane as model hydrocarbons. Ethylene uptake was partially inhibited by CO and H2O when fed separately. When both were added, the loss in ethylene uptake was 90% relative to the condition with no H2O or CO. Dodecane uptake was unchanged under all conditions tested. During a temperature ramp, ethylene desorbed and was combusted to CO2 and H2O over active Pd centers. Further, oxidation light-off of dodecane generated an exotherm which caused rapid desorption of the remaining hydrocarbon species from the zeolite. For both hydrocarbons, CO co-feed led to a decreased oxidation light-off temperature, and therefore lower desorption temperature. By pretreating the catalyst in CO and H2O at 80 °C, and even after removing CO from the feed, the enhanced oxidation light-off behavior was observed. DRIFTS characterization shows that some form of oxidized Pd was reducible to Pd0 by CO at 80 °C only in the presence of H2O. Further, this reduction appears reversible by high temperature oxygen treatment. We speculate that this reduced Pd phase serves as the active site for low temperature hydrocarbon oxidation.
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Li, Yajun, Shu Jiang, Zhenglong Jiang, Hao Liu, and Bingxi Li. "Reconstruction of the Cenozoic History of Hydrocarbon Fluids from Rifting Stage to Passive Continental Margin Stage in the Huizhou Sag, the Pearl River Mouth Basin." Geofluids 2017 (2017): 1–32. http://dx.doi.org/10.1155/2017/4358985.
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The Eocene lacustrine sediments are the primary source rocks in the Huizhou Sag of the Pear River Mouth Basin. This study employs basin modeling for four representative wells and two profiles in the Huizhou Sag to reconstruct the process of generation, expulsion, migration, and accumulation of hydrocarbon fluids. The Eocene source rocks started to generate hydrocarbon at 33.9 Ma and are currently in a mid-mature and postmature stage. Hydrocarbons are mainly expelled from the Eocene Wenchang Fm, and the contribution of the Eocene Enping formation is minor. Under the driving forces of buoyancy and excess pressure, major hydrocarbons sourced from the Eocene source rocks firstly migrated laterally to the adjacent Eocene reservoirs during the postrift stage, then vertically via faults to Oligo-Miocene carrier beds, and finally laterally to the structural highs over a long distance during the Pliocene-Quaternary Neotectonic stage, which is controlled by both structural morphology and heterogeneity of carrier beds. Fault is the most important conduit for hydrocarbon fluid migration during the Neotectonic stage. Reactivation of previous faults and new-formed faults caused by the Dongsha Movement (9.8–4.4 Ma) served as vertical migration pathways after 10.0 Ma, which significantly influenced the timing of hydrocarbon accumulation in the postrift traps.
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Shuster, Vladimir L., Alexander D. Dziublo, and Oleg A. Shnip. "Hydrocarbon deposits in non-anticlinal traps of the Yamal Peninsula of Western Siberia." Georesursy 22, no. 1 (March 30, 2020): 39–45. http://dx.doi.org/10.18599/grs.2020.1.39-45.
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The article considers various types of non-anticlinal traps of the Yamal Peninsula of Western Siberia. The task is to establish the features of their formation and structure. Gas and gas condensate deposits were allocated in the Akhskian formation of the Neocomian section, associated with wedge-shaped traps (Bovanenkovsky, Kharasaveysky fields). This type of lithologically-shielded traps was formed due to clastic material entering the territory of the Yamal Peninsula from the East Siberian Platform, the Yenisei Ridge (from the east) and the Ural Mountains (from the west). Sand and clay material accumulated along the path of underwater hills, where wedging zones formed. Traps of various types are developed in the Jurassic deposits of the region. Traps of tectonically shielded type are formed in areas of the active influence of discontinuous disturbances on the structure of the section (for example, on the Nurminsky Swell). Lithologically-shielded traps are formed on the slopes of the erosive remnants of the paleorelief in zones of terrigenous horizons wedging. Such traps are also formed in zones of their screening by the surface of the pre-Cretaceous erosion. The considered examples made it possible to establish the confinement of various types of traps to the sediment section and their distribution over the area of the Yamal region.
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Parinos, C., A. Gogou, I. Bouloubassi, R. Pedrosa-Pàmies, I. Hatzianestis, A. Sànchez-Vidal, G. Rousakis, D. Velaoras, G. Krokos, and V. Lykousis. "Occurrence, sources and transport pathways of natural and anthropogenic hydrocarbons in deep-sea sediments of the Eastern Mediterranean Sea." Biogeosciences Discussions 9, no. 12 (December 13, 2012): 17999–8038. http://dx.doi.org/10.5194/bgd-9-17999-2012.
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Abstract. Surface sediments collected from deep basins (22 stations, 1018–4087 m depth) of the Eastern Mediterranean Sea (EMS) were analyzed for aliphatic, triterpenoid and polycyclic aromatic hydrocarbons (PAHs) as tracers of natural and anthropogenic inputs. Concentrations of total aliphatic hydrocarbons (TAHC), n-alkanes (NA) and the Unresolved Complex Mixture (UCM) of aliphatic hydrocarbons ranged from 1.34 to 49.2 µg g−1, 145 to 4810 ng g−1 and 0.73 to 36.7 µg g−1, respectively, while total PAHs (TPAH25) concentrations ranged from 11.6 to 223 ng g−1. Molecular profiles of aliphatic hydrocarbons and PAHs reflect the contribution of both natural (epicuticular plant waxes) and anthropogenic (degraded petroleum products, unburned fossil fuels and combustion of petroleum, grass, wood and coal) compounds in deep EMS sediments, with hydrocarbon mixtures displaying significant regional variability. Hydrocarbon concentrations correlated significantly with the Total Organic Carbon (TOC) content of sediments, indicating that organic carbon exerts an important control on their transport and fate in the study area, while strong sub-basin and mesoscale variability of water masses also impact their regional characteristics. Major findings of this study support that deep basins/canyons of the EMS could act as traps of both natural and anthropogenic hydrocarbons.
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Kerimov, V. Yu, M. G. Leonov, A. V. Osipov, R. N. Mustaev, and Vu Nam Khai. "Hydrocarbons in the basement of the South China Sea (Vietnam) shelf and structural-tectonic model of their formation." Геотектоника, no. 1 (April 1, 2019): 44–61. http://dx.doi.org/10.31857/s0016-853x2019144-61.
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Research of genesis of hydrocarbon accumulations located within pre-Cenozoic basement of the South China Sea shelf (Vietnam) presented. Formation of hydrocarbon deposits is confined to the protrusive massifs of granites that have undergone structural and tectonic processing at the stage of prototectonics and postmagmatic tectonics. The totality of post-structure-forming processes led to a change in the viscosity properties of rocks, to their tectonic and material heterogeneity and stratification and, as a consequence, to vertical and lateral redistribution in space with the formation of granite protrusions. The mechanisms of formation of voids and oil and gas traps within the protrusions are considered. Based on the similarity of the geochemical characteristics and biomarker parameters of the oils and organic matter in the Oligocene-Miocene sediments and in the basement rocks, a conclusion has been made about the organic nature of the oils in the basement of the shelf of the South China Sea (Vietnam). Possible mechanisms of migration and accumulation of hydrocarbons in basement rocks are considered. It is confirmed that the formation of hydrocarbon deposits occurred due to lateral and downward migration of hydrocarbons through the contact area from the Oligocene-Miocene source rocks into crystalline massifs — into voids and increased fracture zone in the protrusions.
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Faisal Miraj, Muhammad Armaghan, Muhammad Yaseen, Abid Ali, Rana Faizan Saleem, Sher Afgan, and Palwasha Shahzad Rathore. "Structural and Economic Analysis of Meyal Oil Field in the Northern Potwar Deformed Zone, Upper Indus Basin, Pakistan." International Journal of Economic and Environmental Geology 11, no. 4 (March 16, 2021): 65–71. http://dx.doi.org/10.46660/ijeeg.vol11.iss4.2020.521.
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Potwar sub-basin is famous for its structural style, hydrocarbon exploration and production activities from Cambrian to Pliocene rocks. Foreland basin related subsurface structures, in the presence of source and seal rocks offer a variety of traps to host hydrocarbons. Meyal Oil field, situated in the NW Potwar sub-basin, is a hydrocarbon resource for the country. Subsurface structures of Meyal area were outlined by interpreting two strike and four dip lines in IHS Kingdom suite. Borehole data of MYL-10, MYL-12 and MYL-13 exploratory wells were incorporated to improve the subsurface understanding. A total five prominent reflectors of Permian, Triassic, Jurassic, Paleocene and Eocene rocks were marked on the seismic sections. The seismic interpretation shows a post Eocene pop-up structure flanked by a back thrust and a fore thrust. Moreover, the time structure maps for Meyal area display a doubly plunging and faulted anticline as a result of south directed compression. Four isochron maps show thickness variation in Permian to Eocene sediments in the study area. The results of interpretation show favorable structural trap for economic hydrocarbon exploration.
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Cowley, R., and G. W. O'Brien. "IDENTIFICATION AND INTERPRETATION OF LEAKING HYDROCARBONS USING SEISMIC DATA:A COMPARATIVE MONTAGE OF EXAMPLES FROM THE MAJOR FIELDS IN AUSTRALIA'S NORTHWEST SHELF AND GIPPSLAND BASIN." APPEA Journal 40, no. 1 (2000): 119. http://dx.doi.org/10.1071/aj99008.
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An extensive volume of 3D seismic data over a number of oil and gas fields in Australia's North West Shelf and Gippsland Basin has been examined for evidence of the effects of hydrocarbon migration and/or leakage. For comparative purposes, 2D and 3D data have also been studied over a number of adjacent traps, including dry traps and partially to completely breached accumulations. Fields and traps investigated include Bayu-Undan, Jabiru, Skua, Swift and Tahbilk in the Bonaparte Basin, Cornea in the Browse Basin, North Rankin, Chinook, Macedon, Enfield and Zeewulf in the Carnarvon Basin, and Kingfish in the Gippsland Basin. The principal goal of the study is to provide representative case studies from known fields so that, in undrilled regions, the exploration uncertainties associated with the issues of hydrocarbon charge and trap integrity might be reduced.Direct indicators of hydrocarbon migration and/or leakage are relatively rare throughout the basins studied, though the discoveries themselves characteristically show seismic anomalies attributable to hydrocarbon leakage. The nature and intensity of these hydrocarbon-related seismic effects do, however, vary dramatically between the fields. Over traps such as Skua, Swift, Tahbilk and Macedon, they are intense, whereas over others, for example Chinook and North Rankin, they are quite subtle. Hydrocarbon-related diagenetic zones (HRDZs), which had been identified previously above the reservoir zones of leaky traps within the Bonaparte Basin, have also been recognised within the Browse, Carnarvon, Otway and Gippsland Basins. HRDZs are the most common leakage indicators found and are identified easily via a combination of high seismic amplitudes through the affected zone, time pull-up and degraded stack response of underlying reflectors. In some cases (the Skua and Macedon Fields), the HRDZs actually define the extent of the accumulations at depth.Anomalous, subtle to strong, seismic amplitude anomalies are associated with the majority of the major fields within the Carnarvon Basin. The strength and location of the anomalies are related to a complex interplay between trap type (in particular four-way dip-closed versus fault dependent), top seal capacity, fault seal integrity, and charge history. In some areas within the Carnarvon, Browse and Bonaparte Basins, shallow amplitude anomalies can be related directly to gas chimneys emanating from the reservoir zone itself. In other instances, the continuous migration of gas from the reservoir has produced an assortment of pockmarks, mounds and amplitude anomalies on the present day sea floor, which all provide evidence of hydrocarbon seepage. In the Browse Basin, strong evidence has been found that many of the modern carbonate banks and reefs in the region were initially located over hydrocarbon seeps on the palaeo-seafloor.The examples and processes presented demonstrate that the analysis of hydrocarbon leakage indicators on seismic data can help to better understand exploration risk and locate subtle hydrocarbon accumulations. In mature exploration provinces, this methodology may lead to the identification of subtle accumulations previously left undetected by more conventional methods. In frontier regions, it can help to identify the presence of a viable petroleum system, typically the principal exploration uncertainty in undrilled regions.
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Shuster, V. L. "Methodical approach to identifying and searching for oil and gas deposits in complex non-anticlinal traps." Actual Problems of Oil and Gas, no. 30 (December 21, 2020): 26–31. http://dx.doi.org/10.29222/ipng.2078-5712.2020-30.art3.
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The article considers the goals, objectives, methods and types of geological and geophysical research, criteria for identifying and searching for oil and gas deposits associated with non-anticlinal traps. Proposals are made to improve and systematize the existing methodical approach to solving the problem of detecting and searching for hydrocarbon deposits in non-anticlinal traps.
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Wang, Ziyi, Zhiqian Gao, Tailiang Fan, Hehang Zhang, Lixin Qi, and Lu Yun. "Hydrocarbon-bearing characteristics of the SB1 strike-slip fault zone in the north of the Shuntuo Low Uplift, Tarim Basin." Petroleum Geoscience 27, no. 1 (July 1, 2020): petgeo2019–144. http://dx.doi.org/10.1144/petgeo2019-144.
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The SB1 strike-slip fault zone, which developed in the north of the Shuntuo Low Uplift of the Tarim Basin, plays an essential role in reservoir formation and hydrocarbon accumulation in deep Ordovician carbonate rocks. In this research, through the analysis of high-quality 3D seismic volumes, outcrop, drilling and production data, the hydrocarbon-bearing characteristics of the SB1 fault are systematically studied. The SB1 fault developed sequentially in the Paleozoic and formed as a result of a three-fold evolution: Middle Caledonian (phase III), Late Caledonian–Early Hercynian and Middle–Late Hercynian. Multiple fault activities are beneficial to reservoir development and hydrocarbon filling. In the Middle–Lower Ordovician carbonate strata, linear shear structures without deformation segments, pull-apart structure segments and push-up structure segments alternately developed along the SB1 fault. Pull-apart structure segments are the most favourable areas for oil and gas accumulation. The tight fault core in the centre of the strike-slip fault zone is typically a low-permeability barrier, whilst the damage zones on both sides of the fault core are migration pathways and accumulation traps for hydrocarbons, leading to heterogeneity in the reservoirs controlled by the SB1 fault. This study provides a reference for hydrocarbon exploration and development of similar deep-marine carbonate reservoirs controlled by strike-slip faults in the Tarim Basin and similar ancient hydrocarbon-rich basins.
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Yuan, Hong Qi, Ying Hua Yu, and Fang Liu. "Controlling Factors of Hydrocarbon Accumulation in Talaha-Changjiaweizi Area." Advanced Materials Research 734-737 (August 2013): 1175–78. http://dx.doi.org/10.4028/www.scientific.net/amr.734-737.1175.
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Based on the analysis of the relationships between the conditions of structures, sedimentations, source rocks, cap rocks, faults, oil and gas migration passages and traps and hydrocarbon accumulation, the controlling factors of hydrocarbon accumulation and distribution was studied in Talaha-changjiaweizi area. It is held that the source rocks control the hydrocarbon vertical distribution, the drainage capabilities control the hydrocarbon plane distribution, fracture belts control the hydrocarbon accumulation of Talaha syncline, underwater distributary channel is a favorable accumulation environment and reservoir physical properties control the oil and water distributions. Therefore, it is concluded that source rocks, fracture belts, sedimentary microfacies and reservoir physical properties are the main controlling factors of hydrocarbon accumulation and distribution in Talaha-changjiaweizi area.
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Edmundson, Isabel, Atle Rotevatn, Roy Davies, Graham Yielding, and Kjetil Broberg. "Key controls on hydrocarbon retention and leakage from structural traps in the Hammerfest Basin, SW Barents Sea: implications for prospect analysis and risk assessment." Petroleum Geoscience 26, no. 4 (December 19, 2019): 589–606. http://dx.doi.org/10.1144/petgeo2019-094.
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Evidence of hydrocarbon leakage has been well documented across the SW Barents Sea and is commonly associated with exhumation in the Cenozoic. While fault leakage is thought to be the most likely cause, other mechanisms are possible and should be considered. Further study is required to understand what specific mechanism(s) facilitate such leakage, and why this occurs in some locations and not others. In a case study of the Snøhvit Field, we use seismic and well data to quantify fault- and top-seal strength based on mechanical and capillary threshold pressure properties of fault and cap rocks. Magnitude and timing of fault slip are measured to acknowledge the role that faults play in controlling fluid flow over time. Results based on theoretical and in situ hydrocarbon column heights strongly indicate that across-fault and top-seal breach by capillary threshold pressure, and top-seal breach by mechanical failure are highly unlikely to have caused hydrocarbon leakage. Instead, top-seal breach caused by tectonic reactivation of identified faults is likely to have facilitated hydrocarbon leakage from structural traps. The results of this case study acknowledge the different mechanisms by which hydrocarbons can leak from a structural trap. Employing both a holistic and quantitative approach to assessing different seal capacities reduces the likelihood that a particular cause of hydrocarbon leakage is overlooked. This is particularly relevant for the Snøhvit Field in its dual capacity as a producing gas field and as a carbon sequestration site since both systems rely on a thorough understanding of seal capacity and leakage potential.
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Kryvosheyev, V. T., V. V. Makogon, and Ye Z. Ivanova. "THE MAIN RESERVE OF ACCELERATED EFFECTIVE OPENING OF OIL AND GAS FIELDS IN UKRAINE." Мінеральні ресурси України, no. 1 (April 25, 2019): 31–37. http://dx.doi.org/10.31996/mru.2019.1.31-37.
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Economic hardship in Ukraine during the years of independence led to a sharp reduction of exploration work on oil and gas, a drop in hydrocarbon production, a decrease in inventories and a sharp collapse of research work to ensure the growth of hydrocarbon reserves.The hydrocarbon potential of various sources of Ukrainian subsoil is quite powerful and can provide future energy independence of the country. Potential hydrocarbon resources in traditional traps of various types are exhausted by only 25 %. Ukraine has recently experienced so-called “shale gas boom”. The experience of extraction of shale gas in desert areas of the United States can not be repeated in densely populated Ukraine in the absence of such powerful shale strata, resource base, necessary infrastructure, own technologies and techniques and economic, environmental and social risks.Taking into account the fuel and energy problems of the state, we constantly throughout the years of independence oriented the oil and gas industry and the authorities on the active use of our own reserves and opportunities for accelerated opening of new oil and gas fields.The results of geological exploration work in the old oil and gas basins at the high level of their study indicate that deposits in non-structural traps dominate among open deposits.A complex of sequence-stratigraphical, lithology-facies and lithology-paleogeographical studies is being successfully used to forecast undeformational traps in well-studied oil and gas bearing basin of the Ukraine – the Dniprovsko-Donetsky basin. The authors predict wide development of stratigraphic, lithologic, tectonic and combined traps in terrigenous sediments of Tournaisian and Visean age, reef-carbonate massifs of the lower Tournaisian, lower and middle Visean age and others. They should become the basis for exploration of oil and gas fields for the near and medium term and open the second breath of the basin.
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Ning, Zhao, Gao Xia, Huang Jiangqin, Chen Zhongmin, and Zhang Guangya. "Sedimentary Characteristics and Lithological Trap Identification of Distant Braided Delta Deposits: A Case on Upper Cretaceous Yogou Formation of Termit Basin, Niger." E3S Web of Conferences 53 (2018): 03020. http://dx.doi.org/10.1051/e3sconf/20185303020.
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Lithological trap identification in thin sand and thick shale layers is still a challenge for hydrocarbon exploration. Based on the high-resolution sequence stratigraphy theory and the establishment of high-resolution sequence stratigraphy framework with seismic-well tie, the dynamic deposition process of braided delta sands on late Cretaceous Yogou formation has been analyzed on 62 wells in passive rifting Termit basin with multi-stages depressions and reversals. (1) Six kinds of sedimentary microfacies and three major reservoir sands with multi-stages vertical stacking and lateral migration are in late Cretaceous; (2) Based on accommodation space/Sediments supply change and depositional progress, sedimentary facies distribution evolution has been done according to sands thickness statistics of sedimentary micro-facies, and narrow-time seismic attributes and slices analysis, multi-sources braided delta depositional model has been concluded; (3) Based on source rock and caprock evaluation, with reservoir sands distribution and faults impact on Yogou formation of Termit basin, four types of traps, including structure-lithology, Structure-strata, stratigraphic and lithology are concluded. Traps influencing factors, i.e., structure geometry, sands distribution, paleotopography, stratigraphy cycling, sand/shale lateral connection, reservoir quality and so on, have different impacts on these traps, and different lithologic-stratigraphy traps have different exploration risks. Structure geometry and sands distribution are very important for the structure-lithology traps; structure geometry and paleotopography are the key factors in Structure-strata traps. Sands distribution and reservoir quality can be focused on lithology traps. Moreover, paleotopography and sand/shale lateral connection are significant on stratigraphic traps. Therefore, different hydrocarbon accumulation types of lithological traps have been established.
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Mandelbaum, M. M., and A. I. Shamal. "Geophysical methods of oil and gas exploration in cambrian and precambrian sedimentary rocks of the Siberian Platform." Exploration Geophysics 20, no. 2 (1989): 37. http://dx.doi.org/10.1071/eg989037a.
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The Siberian Platform is the largest hydrocarbon-bearing sedimentary basin in the USSR. The conditions encountered in geophysical exploration in this basin are uniquely difficult. This very old sedimentary complex is characterised by abrupt changes in physical properties reflecting the presence of dolerites and tuffs, changes in salt thickness, and complex structure. Petroleum traps are controlled by low amplitude structures in the salt complex, although reservoir properties are variable, so that most traps are stratigraphic. This leads to the use of frequency content of seismic data to identify traps and electrical and time domain EM techniques to confirm the presence of the traps.
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Kurkin, A. A., N. V. Yankova, V. I. Kuznetsov, and S. K. Stulikov. "BERRIASIAN-HAUTERIVIAN SHALE SEQUENCE AND ASSOCIATED PINCH-OUT TRAP PROSPECTS OF THE YAMAL PENINSULA." Oil and Gas Studies, no. 1 (March 1, 2018): 13–21. http://dx.doi.org/10.31660/0445-0108-2018-1-13-21.
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Based on detailed seismic and well data interpretation, a Berriasian-Early Hauterivian voskhodnaya sequence of shale was distinguished as a part of Akhskaya suite in the south-west of the Yamal Peninsula. Subsequent conventional west dipping clinoforms are pinching-out on the top of the sequence, forming stratigraphic traps, characterized by seismic anomalies. Hydrocarbon prospectivity of the traps is proved by well tests.
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van Balen, R. T., F. van Bergen, C. de Leeuw, H. Pagnier, H. Simmelink, J. D. van Wees, and J. M. Verweij. "Modelling the hydrocarbon generation and migration in the West Netherlands Basin, the Netherlands." Netherlands Journal of Geosciences - Geologie en Mijnbouw 79, no. 1 (March 2000): 29–44. http://dx.doi.org/10.1017/s0016774600021557.
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AbstractThe hydrocarbon systems of the Mesozoic, inverted West Netherlands Basin have been analyzed using 2-D forward modelling. Three source rocks are considered in the modelling: Lower Jurassic oil-prone shales, Westphalian gas-prone coal deposits, and Lower Namurian oil-prone shales. The Lower Namurian hydrocarbon system of the basin is discussed for the first time.According to the modelling results of the Early Jurassic oil system, the oil accumulations were filled just after the main inversion event. Their predicted locations are in agreement with exploration results. Modelling results of the Westphalian gas system, however, show smaller and larger sized accumulations at unexplored locations. The gas reservoirs were filled during the Late Jurassic-Early Cretaceous rifting phase. Results of modelling of the Lower Namurian oil system indicate that gas formed by secondary cracking of the oils can have mixed with the Westphalian coal-derived gas. Such a mixing is inferred from geochemical analyses. The existence of a Lower Namurian hydrocarbon system in the West Netherlands Basin implies that hydrocarbons are possibly trapped in the Westphalian and Namurian successions. These potential traps in the basin have not yet been explored.
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Connolly, David L. "Visualization of vertical hydrocarbon migration in seismic data: Case studies from the Dutch North Sea." Interpretation 3, no. 3 (August 1, 2015): SX21—SX27. http://dx.doi.org/10.1190/int-2015-0007.1.
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Previous 3D visualization studies in seismic data have largely been focused on visualizing reservoir geometry. However, there has been less effort to visualize the vertical hydrocarbon migration pathways, which may provide charge to these reservoirs. Vertical hydrocarbon migration was recognized in normally processed seismic data as vertically aligned zones of chaotic low-amplitude seismic response called gas chimneys, blowout pipes, gas clouds, mud volcanoes, or hydrocarbon-related diagenetic zones based on their morphology, rock properties, and flow mechanism. Because of their diffuse character, they were often difficult to visualize in three dimensions. Thus, a method has been developed to detect these features using a supervised neural network. The result is a “chimney” probability volume. However, not all chimneys detected by this method will represent true hydrocarbon migration. Therefore, the neural network results must be validated by a set of criteria that include (1) pockmarked morphology, (2) tie to shallow direct hydrocarbon indicators, (3) origination from known or suspected source rock interval, (4) correlation with surface geochemical data, and (5) support by basin modeling or well data. Based on these criteria, reliable chimneys can be extracted from the seismic data as 3D geobodies. These chimney geobodies, which represent vertical hydrocarbon migration pathways, can then be superimposed on detected reservoir geobodies, which indicate possible lateral migration pathways and traps. The results can be used to assess hydrocarbon charge efficiency or risk, and top seal risk for identified traps. We investigated a case study from the Dutch North Sea in which chimney processing results exhibited vertical hydrocarbon pathways, originating in the Carboniferous age, which provided the charge to shallow Miocene gas sands and deep Triassic prospects.
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Hao, Hui Zhi, and Li Juan Tan. "The Characteristic of Oil and Gas Accumulation and Main Factors of Reservoir Enrichment in SZ36-1 Region." Applied Mechanics and Materials 737 (March 2015): 859–62. http://dx.doi.org/10.4028/www.scientific.net/amm.737.859.
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The hydrocarbon reservoirs which have been found in SZ36-1 region are located in Liaoxi low uplift and dominated by structural traps. The principle source rock is the first and the third member of the Neogen Shahejie Formation and the main reservoir type is delta sand body which mainly located in the second member of Shahejie Formation. Oil reservoirs are mostly in normal pressure and are possess characteristic of late hydrocarbon accumulation. Hydrocarbon accumulation is mainly controlled by fault,reservoir-cap rock combination, and petroleum migration pathways. Lateral distribution of hydrocarbon reservoirs is mostly controlled by reservoir rocks, while the vertical distribution is controlled by fault.
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Punanova, S. A. "The relevance of mapping non-anticlinal traps and features of their classifications." Actual Problems of Oil and Gas, no. 30 (December 21, 2020): 13–25. http://dx.doi.org/10.29222/ipng.2078-5712.2020-30.art2.
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The study of hydrocarbon reservoirs in the sediments of sedimentary basins indicates a significant increase in the number of non-anticlinal, complex, unconventional, combined traps, which is currently noted during the discovery of large oil and gas fields with high resources. Based on the analysis of literature sources, the article provides a brief overview of the classifications of traps developed both for regional levels and for local operations in specific oil and gas regions. Examples of the development of subtle extended traps in shale carbonaceous formations are considered.
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Woods, E. P. "VULCAN SUB-BASIN FAULT STYLES — IMPLICATIONS FOR HYDROCARBON MIGRATION AND ENTRAPMENT." APPEA Journal 32, no. 1 (1992): 138. http://dx.doi.org/10.1071/aj91012.
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Several structural domains are recognised within the Vulcan Sub-basin, Timor Sea. These domains developed during the Jurassic rifting phase and are separated by major transfer zones which trend in a northwest-southeast direction. Within each domain are frequent third order transfers which sub-divide the main northeast trending fault blocks into numerous compartments. These enable structural hydrocarbon traps to be formed, despite a predominant regional dip. They also affect migration pathways.Jurassic fault styles include detached rotational blocks, salt-associated features, tilted fault blocks and 'hourglass' horsts and grabens. These generally have a northeast-southwest orientation. The transfer faulting complicates these features and forms zones of structural complexity with associated poor seismic data quality. A separate fault episode in the north of the sub-basin during the Tithonian resulted in an east-west fault set overprinting the earlier structuring.Intra-Cretaceous fault movement is also recognised and has an important role in early hydrocarbon entrapment.Structural reactivation during the Late Miocene/Early Pliocene of the earlier fault sets modified the geometry of many existing traps. Numerous new traps may also have formed as a result of this tectonism. In many places the resulting geometry is complex, particularly where the younger fault orientation is at an angle to the main Oxfordian fault set. The late-stage movement is primarily extensional, manifested by predominantly normal faults; overall, however, a varying component of strike slip is likely. A divergent strike-slip zone is recognised at the southwest end of the Cartier Trough.The effects of the late stage tectonism tend to mask the seismic expression of Mesozoic hydrocarbon traps resulting in many wells being drilled off-structure at the target horizon. An understanding of the deeper structuring should result in further discoveries in this prospective basin.
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Wang, Wei, Guomin Chen, Lin Wang, Shenjian Wang, and Qilin Wu. "Significance and purpose of the comprehensive evaluation of hydrocarbon traps." IOP Conference Series: Earth and Environmental Science 658 (February 20, 2021): 012014. http://dx.doi.org/10.1088/1755-1315/658/1/012014.
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O'Brien, Geoffrey, Chris Boreham, Hywel Thomas, and Peter Tingate. "Understanding the critical success factors determining prospectivity—Otway Basin, Victoria." APPEA Journal 49, no. 1 (2009): 129. http://dx.doi.org/10.1071/aj08009.
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The critical success factors that control hydrocarbon prospectivity in the Otway Basin have been investigated using petroleum systems approaches. It have revealed that greater than 99% of the discovered hydrocarbons in the Victorian Otway Basin have been sourced from Austral 2 (Albian-Aptian) source rocks and that these Austral 2-sourced hydrocarbon accumulations either directly overlieâor are located within 3,000 mâof actively generating Austral 2 source rock kitchens. Importantly, the zones of greatest prospectivity are located where these source rocks have been actively generating and expelling hydrocarbons throughout the Late Paleogene, primarily as a result of sediment loading associated with progradation of the Heytesbury shelfal carbonates. This peak generation window occurs at an average depth of approximately 2,500â3,500 m sub-mud across much of the basin, which has allowed prospective hydrocarbon fairways to be mapped out, thereby highlighting areas of greatest prospectivity. The close spatial proximity of the actively generating source rocks to the accumulations is due to several factors, which include overall poor fault seal in the basin (success cases occur where charge rate exceeds leakage rate) and relatively complex and tortuous migration fairways (which means that large volumes of hydrocarbons are only focussed and migrate for relatively short distances). In areas within which the Austral 2 system comprises the sole hydrocarbon chargeâsuch as across the inner Mussel Platformâthe reservoired gas compositions are typically very dry. In contrast, the gas compositions in accumulations sited along or immediately inboard of the Mussel-Tartwaup Fault Zone (La Bella, Geographe and Thylacine) are significantly wetter and also have higher CO2 contents. Throughout this area, the wetter components of the reservoired hydrocarbon inventory may have a source contribution from within the basal (Turonian) part of the younger Austral 3 system, in sequences that have been confirmed by δTLogR analysis to be significantly enriched in total organic carbon content. This observation has significantly upgraded the potential of the upper shelf areas, where a relatively more liquids-rich hydrocarbon inventory might be expected. The CO2 in accumulations located along the Mussel-Tartwaup Fault Zone is interpreted, based upon new helium isotope data, to be of mixed deep crustal-magmatic origin. This CO2 is believed to have migrated from great depth up the crustal-scale fault arrays into the shallower Late Cretaceous reservoirs. Here, the CO2 mixed with crustal gases, typified by helium with a mixed magmatic-crustal isotopic signature. Throughout this area, the traps tend to be large and henceâeven though their CO2 contents are only 8â12%âthe total CO2 volumes contained in these accumulations are much greater than those in the very CO2-richâbut volumetrically small trapsâlocated onshore (e.g. Boggy Creek). Hydrocarbon accumulations located on the inner shelf, such as Minerva and Casino, have distinctly lower CO2 contents, perhaps because large displacement, through-going faults are lacking in this area. These observations collectively provide a predictive regional framework for understanding the likely distribution of commercial hydrocarbon accumulations in the offshore Otway Basin, as well as for forecasting the gas wetnesses and CO2 contents of undrilled exploration targets in both well-explored and frontier parts of the basin.
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Bretan, Peter G., Graham Yielding, and Einar Sverdrup. "A knowledge database of hanging-wall traps that are dependent on fault-rock seal." Geological Society, London, Special Publications 496, no. 1 (August 7, 2019): 209–22. http://dx.doi.org/10.1144/sp496-2018-157.
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AbstractHanging-wall traps are successful trapping styles with discoveries made in many sedimentary basins worldwide. Examples of hanging-wall traps are documented in the literature but very few describe the role played by fault-rock seal on trap integrity. This contribution focuses on hanging-wall traps that are dependent on fault-rock seal. Analysis of 18 examples of hanging-wall traps has revealed that the hydrocarbon column height trapped by fault-rock seal is typically less than 190 m. Cross-plots of shale gouge ratio (SGR) and buoyancy pressure from hanging-wall traps have a similar data distribution to published SGR–buoyancy pressure calibration plots. The similarity in data distribution indicates a similarity in the overall fault-sealing mechanism: namely, the capillary fault sealing through the incorporation of clay/shale material into the fault zone. Published ‘global’ calibration plots of SGR v. buoyancy pressure can be used to evaluate the sealing or non-sealing risk of hanging-wall traps in the same manner as for footwall traps.
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Brincat, M. P., G. W. O’Brien, M. Lisk, M. De Ruig, and S. C. George. "HYDROCARBON CHARGE HISTORY OF THE NORTHERN LONDONDERRY HIGH: IMPLICATIONS FOR TRAP INTEGRITY AND FUTURE PROSPECTIVITY." APPEA Journal 41, no. 1 (2001): 483. http://dx.doi.org/10.1071/aj00023.
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Re-appraisal of the oil charge history of the northern Londonderry High has identified numerous palaeo-oil columns of up to 80 m in height. An integration of the oil charge history, stress field analysis and contemporary seepage data allows a subdivision of the well results into three distinct provinces. These each have distinct charge histories that reflect differences in potential source kitchens and all have been adversely affected by the Neogene collision of the Australian and Southeast Asian plates. Traps located on the northern and northeastern Londonderry High have experienced high oil charge rates at the Mesozoic level, with nearly all valid traps showing evidence of prior oil accumulation. Breaching of these oil columns in the Neogene appears to be related to the orientation of the contemporary stress field, which promotes shear failure on the faults reliant for seal. Present day hydrocarbon migration indicators, such as Synthetic Aperture Radar (SAR) data show differences in seepage response between the northern and northeastern Londonderry High, with prolific current day seepage restricted to the northern province. Rapid subsidence associated with plate collision has accelerated maturation in the northern province to create these strong seepage anomalies over this region. The absence of seepage over the breached oil columns of the northeastern province indicates that either, oil charge has ceased to this area or that hydrocarbon leakage is episodic in nature.In contrast, results from the northwestern province show no evidence of prior oil accumulation, despite many wells having tested valid traps. These data point to either a lack of connected oil migration pathways or an impoverished source kitchen for liquid hydrocarbons. Low levels of seepage in the northwestern Londonderry High detected by the SAR data are minor compared with other parts of the Timor Sea and consistent with migration continuing at the current day. The overall prospectivity for fault bound traps in the study area appears to be low, due to extensive fault reactivation producing low fault seal integrity. Stratigraphic plays that do not rely on faults for seal, particularly in the northern and northeastern provinces, represent an alternative play concept at the Jurassic level. At shallower levels in the Cretaceous, subtle four-way dip closed structures are often enhanced by the reactivation process and could be ideally positioned to receive remigrated oil from breached Jurassic oil accumulations.
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Shuster, V. L. "Methodical approach to forecasting zones in oil and gas bearing basins favorable for the formation of non-anticlinal traps." Actual Problems of Oil and Gas, no. 29 (November 19, 2020): 64–71. http://dx.doi.org/10.29222/ipng.2078-5712.2020-29.art5.
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The article discusses the goals, objectives, methods and types of geological and geophysical studies, as well as the forecast criteria for non-anticlinal oil and gas traps at the regional stage of exploration. Proposals are made to improve and systematize existing methods for predicting non-anticlinal traps. Geological and geophysical data on hydrocarbon deposits and exploration areas of Western Siberia are utilized. Comprehensive analysis of seismic data, well logs and core data is carried out using modern research methods.
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Punanova, S. A., and A. V. Samoilova. "Prediction of the phase state of hydrocarbon deposits in traps of a combined structure." Actual Problems of Oil and Gas, no. 33 (September 17, 2021): 15–27. http://dx.doi.org/10.29222/ipng.2078-5712.2021-33.art2.
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The possibilities of predicting the phase state of hydrocarbon deposits by geochemical methods are considered. The article briefly describes the well-known gas-geochemical and petrochemical forecasting methods, and also proposes to use trace element indicators of fluids for these purposes. Based on the study of the distribution of the trace element composition of oils and condensates in Western Siberia, Turkmenistan, the Caspian Sea region, New Zealand and some other regions, the trace element geochemical indicators of naphthides are recommended for diagnostics of oil and gas condensate systems. The fact of the presence of trace elements in the light fractions of hydrocarbon fluids and the revealed genetic differences between oils and condensates make it possible to use trace element characterization of fluids for practical problems of oil and gas prospecting geology. Since by now hydrocarbon production reserves in anticlinal structures is nearing exhaustion, considerable attention is paid to complex combined traps confined to greater depths and severe thermobaric conditions.
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Kurchikov, A. R., R. I. Timshanov, and E. A. Ustimenko. "ADAPTATION OF THE METHOD OF CHROMATOGRAPHIC ANALYSIS OF GASOLINE TO ACHIEVE PURPOSES OF GEOCHEMICAL PROSPECTING FOR OIL AND GAS." Oil and Gas Studies, no. 6 (January 20, 2019): 16–23. http://dx.doi.org/10.31660/0445-0108-2018-6-16-23.
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Geochemical survey is commonly applied during geological exploration to predict petroleum potential of large areas and to estimate the content of traps identified by the results of seismic survey. C1-C6 hydrocarbon concentrations in samples of surface and subsurface air, soil, snow, water, etc. are used as predictive indicators. At the exploration stage the capabilities of geochemical methods can be significantly expanded by comparing the content of gasoline hydrocarbons in samples of formation fluids and in samples of near-surface sediments. The method of chromatographic analysis of gasolines Chromatec Gazolin has been adapted for sample analysis. The taken measures to increase the sensitivity allowed us to register individual hydrocarbons C1-C10 in concentrations up to 0,01 ppb, which is obviously lower than their background content in the oil prospect areas. The revealed patterns are used in the geological interpretation of geochemical distributions based on theoretical ideas about the subvertical migration of hydrocarbons from the reservoir to the surface.
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Burns, K. A., and S. Codi. "NON-VOLATILE HYDROCARBON CHEMISTRY STUDIES AROUND A PRODUCTION PLATFORM ON AUSTRALIA'S NORTH WEST SHELF." APPEA Journal 38, no. 1 (1998): 626. http://dx.doi.org/10.1071/aj97038.
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In September 1994 and 1995, scientists from the Australian Institute of Marine Science (AIMS) and the Australian Geological Survey Organisation (AGSO) conducted surveys aboard the Research Vessel Lady Basten to determine the dispersion, fates and effects of Produced Formation Water (PFW) discharged from the Harriet A production platform near the Montebello Islands, on the North West Shelf of Australia. This report describes the non-volatile hydrocarbon chemistry studies.We measured the dispersion of the PFW into dissolved and particulate fractions of seawater using moored high volume water samplers, surface screen samplers and moored and drifting sediment traps. We studied bioaccumulation using transplanted oysters, and we measured dispersion into sediment with benthic grabs. Samples were analysed for total non-volatile hydrocarbons and individual hydrocarbon components using ultraviolet fluorescence spectroscopy (UVF), gas chromatography with flame ionisation detection (GC-FID), and GC with mass selective detection (GC/MS). The hydrocarbon concentrations were used to calculate vertical fluxes and the total concentrations of hydrocarbons in the various ecosystem compartments. A mass balance model was then used to calculate the rates of other important dispersion and degradation processes.We estimate the potential zone of biological impact in the water column extends to a distance of approximately 0.5 nmile (900 m). Concentrations of oil in sediments were too low to indicate potential toxicity. By the collaborative application of oceanographic and geochemical techniques to marine environmental problems, we endeavour to provide effective feedback to the oil industry to gauge the effectiveness of their operational strategies in minimising impact in these pristine regions.
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Wang, Aiguo, Liping Yi, Baoli Xiang, Ji Li, Changyu Fan, Chunyu Li, Ni Zhou, and Yi Wang. "Origin of deep heavy oils in the northwestern Junggar Basin (NW China) and implications for gas migration." Energy Exploration & Exploitation 38, no. 4 (February 3, 2020): 819–40. http://dx.doi.org/10.1177/0144598720903390.
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Whether the northwestern Junggar Basin (NW China) has natural gas potential is an urgent but unresolved question. In this study, we discuss the origin of deep heavy oils (>2900 m) and its implication for gas migration and accumulation, based on a comprehensive investigation into physicochemical and geological properties of hydrocarbons in the northern Zhongguai High. Our results indicate that multiple-episode migration of hydrocarbons created four genetic types of oils and three genetic types of hydrocarbon gases and induced widespread gas washing. Relatively low maturity and gas washing are both responsible for the formation of the deep heavy oils. In detail, the migrating late-stage humic-type gases washed the encountered early stage low-maturity oils. The oil reservoirs lost their light fraction and evolved into heavy oils, which are preserved in the deep layer to the present, while the light-end components continued to migrate upward and accumulated as mixed gas pools or vented out of the system. The spatial distributions pattern of source rocks, heavy oils, and mixed gas clearly indicates the migration pathways of humic-type gases, which otherwise are difficult to define in the study area. Because the gases finally migrate into fault belts, their poor preservation condition likely results in the rare discoveries of gas fields. The favorable exploration targets for gas in the area are expected to be fault traps in fault belts, stratigraphic traps along the pinch-out boundary of the Upper Wuerhe Formation, and, particularly, the deep traps in the Mahu Sag.
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Kiomourtzi, P., N. Pasadakis, and A. Zelilidis. "GEOCHEMICAL CHARACTERIZATION OF SATELLITE HYDROCARBON FORMATIONS IN PRINOS-KAVALA BASIN (NORTH GREECE)." Bulletin of the Geological Society of Greece 40, no. 2 (January 1, 2007): 839. http://dx.doi.org/10.12681/bgsg.16728.
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Conditions favoring generation, migration and trapping of hydrocarbons generated economically significant reservoirs in Prinos-Kavala Basin. Prinos oil field and South Kavala gas field are characteristic examples. The submarine fan packed the basin during Upper Miocene. The hydrocarbons were accumulated in turbidites, deposited in a strongly reducing environment, with high sulfur concentration. Evaporates are also deposited before and after the turbidite system. In this study, which is part of a doctorate thesis, extracts retrieved from cored samples of two satellite formations in Prinos-Kavala Basin, Epsilon and Kalirahi, selected at the "Prinos equivalent" formations, have been analyzed, using geochemical methods, and found to exhibit common compositional characteristics. The analysis of biomarkers indicates that the bitumens are immature and non-biodegraded, while their origin is considered mainly algal, with minor terrestrial contribution. Variations on characteristic geochemical ratios between formations, such as Pr/Ph, Ts/Tm, oleanane/hopane and steranes index, are attributed to differences on the type of organic mater input, or the depositional setting of sediments. The identification of the organic matter type, the hydrocarbons generation, migration paths and traps of each structure within the basin is vital for the evaluation of a reliable model of the basin and further hydrocarbon exploration in North Aegean basins
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Duddy, I. R. "FOCUSSING EXPLORATION IN THE OTWAY BASIN: UNDERSTANDING TIMING OF SOURCE ROCK MATURATION." APPEA Journal 37, no. 1 (1997): 178. http://dx.doi.org/10.1071/aj96010.
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Quantitative reconstruction of the thermal and structural histories at key locations in the Otway Basin using an integrated approach based on AFTA® and vitrinite reflectance data reveals a regional pattern of elevated geothermal gradient prior to mid-Cretaceous cooling. Paleogeothermal gradients declined from −50 to 70°C/ km at −95 Ma to present day levels in the range −30 to 40°C/km by around 80 Ma. As a result, significant hydrocarbon generation must have occurred from the thick Late Jurassic to Early Cretaceous Otway Group section during the rapid rift-burial phase that preceded major mid-Cretaceous cooling.Regional decline in geothermal gradient in the Late Cretaceous leads to a 'two-stage' generation history for Otway Group source rocks because subsequent hydrocarbon generation did not recommence until the early maturation effects were overcome by greater Late Cretaceous and Tertiary burial. Such early, high heat flow is regarded as a feature of rift basins, and this results in an inverted pattern of hydrocarbon generation from rift source rocks that is here referred to as 'top-down generation', and which has a key influence on hydrocarbon prospectivity.Analysis of key hydrocarbon discoveries in the basin leads to the conclusion that all significant accumulations can reasonably be inferred to be sourced from the Otway Group, due to 'top-down generation5 delayed until the mid-Tertiary to present-day burial phase. This situation clearly favours hydrocarbon preservation in traps of a range of ages and has the added advantage of limiting the time available for traps to be breached in subsequent structuring episodes.This understanding of the decoupled relationship between the burial and thermal histories provides a sharp focus for further exploration of Otway Group-sourced accumulations, by defining areas with suitable thicknesses of the Late Cretaceous and Tertiary depositional packages which maximise the amount of re-generation since the mid-Tertiary.
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Botor, Dariusz. "Burial and Thermal History Modeling of the Paleozoic–Mesozoic Basement in the Northern Margin of the Western Outer Carpathians (Case Study from Pilzno-40 Well, Southern Poland)." Minerals 11, no. 7 (July 6, 2021): 733. http://dx.doi.org/10.3390/min11070733.
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Hydrocarbon exploration under thrust belts is a challenging frontier globally. In this work, 1-D thermal maturity modeling of the Paleozoic–Mesozoic basement in the northern margin of the Western Outer Carpathians was carried out to better explain the thermal history of source rocks that influenced hydrocarbon generation. The combination of Variscan burial and post-Variscan heating due to elevated heat flow may have caused significant heating in the Paleozoic basement in the pre-Middle Jurassic period. However, the most likely combined effect of Permian-Triassic burial and Late Triassic–Early Jurassic increase of heat flow caused the reaching of maximum paleotemperature. The main phase of hydrocarbon generation in Paleozoic source rocks developed in pre-Middle Jurassic times. Therefore, generated hydrocarbons from Ordovician and Silurian source rocks were lost before reservoirs and traps were formed in the Late Mesozoic. The Miocene thermal overprint due to the Carpathian overthrust probably did not significantly change the thermal maturity of organic matter in the Paleozoic–Mesozoic strata. Thus, it can be concluded that petroleum accumulations in the Late Jurassic and Cenomanian reservoirs of the foreland were charged later, mainly by source rocks occurring within the thrustbelt, i.e., Oligocene Menilite Shales. Finally, this work shows that comprehensive mineralogical and geochemical studies are an indispensable prerequisite of any petroleum system modelling because their results could influence petroleum exploration of new oil and gas fields.
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Abdula, Rzger, Hema Hassan, and Maryam Sliwa. "Petroleum System Modelling of the Akri-Bijeel Oil Field, Northern Iraq: Insights From 1-Dimensional Basin Modelling." UKH Journal of Science and Engineering 4, no. 2 (December 31, 2020): 35–47. http://dx.doi.org/10.25079/ukhjse.v4n2y2020.pp35-47.
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The petroleum system of the Akri-Bijeel oil field shows that the Palaeogene formations such as the Kolosh Formation seem to be immature. However, the Jurassic–Lower Cretaceous source rocks such as those from the Chia Gara, Naokelekan, and Sargelu formations are thermally mature and within the main oil window because their vitrinite reflectance (Ro%) values are >0.55%. The Triassic Kurra Chine and Geli Khana formations are thought to be in the high maturity stage with Ro values ≥1.3% and within the wet and dry gas windows, whereas the older formations are either within the dry gas zone or completely generated hydrocarbon stage and depleted after the hydrocarbons were expelled with subsequent migration to the reservoir rock of the structural traps.
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Li, Bin, Qiqi Li, Wenhua Mei, Qingong Zhuo, and Xuesong Lu. "Analysis of accumulation models of Middle Permian in Northwest Sichuan Basin." Earth Sciences Research Journal 24, no. 4 (January 26, 2021): 419–28. http://dx.doi.org/10.15446/esrj.v24n4.91149.
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Great progress has been made in middle Permian exploration in Northwest Sichuan in recent years, but there are still many questions in understanding the hydrocarbon accumulation conditions. Due to the abundance of source rocks and the multi-term tectonic movements in this area, the hydrocarbon accumulation model is relatively complex, which has become the main problem to be solved urgently in oil and gas exploration. Based on the different tectonic backgrounds of the middle Permian in northwest Sichuan Basin, the thrust nappe belt, the hidden front belt, and the depression belt are taken as the research units to comb and compare the geologic conditions of the middle Permian reservoir. The evaluation of source rocks and the comparison of hydrocarbon sources suggest that the middle Permian hydrocarbon mainly comes from the bottom of the lower Cambrian and middle Permian, and the foreland orogeny promoted the thermal evolution of Paleozoic source rocks in northwest Sichuan to high maturity and over maturity stage. Based on a large number of reservoir physical properties data, the middle Permian reservoir has the characteristics of low porosity and low permeability, among which the thrust nappe belt and the hidden front belt have relatively high porosity and relatively developed fractures. The thick mudstone of Longtan formation constitutes the regional caprock in the study area and the preservation condition is good as a whole. However, the thrusting faults destroyed the sealing ability of the caprock in the nappe thrust belt. Typical reservoir profiles revealed that the trap types were different in the study area. The thrust fault traps are mainly developed in the thrust nappe belt, while the fault anticline traps are developed in the hidden front belt, and the structural lithological traps are developed in the depression belt. The different structural belts in northwest Sichuan have different oil and gas accumulation models, this paper built three hydrocarbon accumulation models by the analysis of reservoir formation conditions. The comprehensive analysis supposed the hidden front belt is close to the lower Cambrian source rock, and the reservoir heterogeneity is weak, faults connected source rock is developed, so it is a favorable oil and gas accumulation area in the middle Permian.
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Wang, Ming Jian, and Xun Hua Zhang. "Lower Paleozoic Hydrocarbon Accumulation Conditions of Middle Uplift in Southern Yellow Sea Basin." Advanced Materials Research 524-527 (May 2012): 1252–55. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1252.
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Guided by the theory of petroleum system, we analyzed the Lower Palaeozoic hydrocarbon accumulation elements and conditions of the Middle uplift of Southern Yellow Sea Basin and concluded the hydrocarbon accumulation pattern. The results showed that: the source rock of lower Palaeozoic in the Middle uplift of Southern Yellow Sea Basin consists of the dark mudstone and carbonate rock; carbonate rock is the main favorable reservoir followed by clastic rock; there are three source-reservoir-cap assemblages; the source rock of Lower Palaeozoic has experienced two hydrocarbon generation stages which are late Silurian and late Middle Triassic; hydrocarbon generated by Lower Palaeozoic source rock can only migrate to the traps near the center of hydrocarbon generation by sandbody and cracks in a short distance; lithologic trap and broad anticlinal trap are the main types in the study area. Through the above analysis, we conclude two accumulation patterns of Lower Palaeozoic in the Middle uplift of Southern Yellow Sea Basin.
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Warren, Marian J., and Mark Cooper. "Classic hydrocarbon traps and analog structures in the southern Canadian Rockies." AAPG Bulletin 101, no. 04 (April 2017): 589–97. http://dx.doi.org/10.1306/011817dig17038.
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Kaukenova, A. S. "Oil and gas potential of the south Turgay basin." Proceedings of higher educational establishments. Geology and Exploration, no. 3 (February 28, 2021): 38–45. http://dx.doi.org/10.32454/0016-7762-2020-63-3-38-45.
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Background. The South Turgay basin has been extensively studied using geological and geophysical methods. To date, the discovery of large oil and gas deposits in its structural traps seems impossible. The deposits, which have been under development for a long time, demonstrate the trend towards depletion. Therefore, a search and exploration of non-anticlinal traps is becoming an important source of hydrocarbon reserves.Aim. To identify zones of non-anticlinal reservoirs and traps.Materials and methods. On the basis of three main criteria for predicting the development of nonanticlinal traps (stratigraphic, lithofacies and structural-tectonic), this paper presents the forecast zones for the development of non-anticlinal traps with oil and gas potential, taking into account the facies diagnostics of the deposits.Results. The traps of regional pinching-out, as well as possible traps of erosion-accumulative and accumulative subgroups, are predominantly developed in the trough. The traps of the regional pinch-out subgroup are most widespread in the Aryskum and Bosingen graben synclines. The traps of the accumulative subgroup are predicted mainly in the Bosingen and Akshabulak graben synclines.Conclusions. According to the obtained results, the South Turgay Basin possesses a significant oil and gas potential in non-anticlinal traps. Lithological reservoirs with thick and widespread mudstones confined to the Jurassic deposits are of particular interest.
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O'Brien, G. W., and E. P. Woods. "HYDROCARBON-RELATED DIAGENETIC ZONES (HRDZs) IN THE VULCAN SUB-BASIN, TIMOR SEA: RECOGNITION AND EXPLORATION IMPLICATIONS." APPEA Journal 35, no. 1 (1995): 220. http://dx.doi.org/10.1071/aj94015.
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Within very localised areas of the Vulcan Subbasin, the Eocene Grebe Formation sandstones are strongly cemented with carbonate. These cemented sands are recognisable on seismic data as zones of anomalously high velocity, and result in both time 'pull-up' and deterioration of the stack response in the underlying section.To determine the nature and origin of these cemented zones, their isotopic, mineralogical and petrologic compositions have been characterised, their seismic response and areal distribution established, and these observations integrated with ~2,730 km of AGSO water column geochemical ('sniffer-type') data.The carbon isotopic compositions of the carbonate within the cemented Grebe sands are diagnostic of carbonates formed principally via the oxidation of migrating, thermogenic hydrocarbons. Oxidation of the hydrocarbons took place in two stages: an earlier phase led to calcite precipitation, whereas a later phase produced (generally subsidiary) ferroan dolomite/ankerite cementation.Areas of known, present-day hydrocarbon seepage from the seafloor, such as over major faults on the Skua Horst and along the Vulcan Sub-basin/ Londonderry High boundary zone, are invariably associated with zones of highly cemented Eocene sands. Similarly, areas of known Tertiary hydrocarbon seepage, such as those associated with the residual oil columns on the Eider Horst, also contain strongly cemented Eocene sandstones.These observations have established a causal relationship between the presence of these Hydrocarbon-Related Diagenetic Zones (or HRDZs) in the Eocene sandstones and Tertiary-Quaternary hydrocarbon seepage. It is likely that most of the cementation occurred during the Late Miocene/Early Pliocene, when the Grebe Formation sands were at a shallow depth of burial(Recognition of this causal association has allowed several insights to be gained into the exploration potential and reactivation history of structures within the Vulcan Sub-basin. Mapping of the areal distribution of the cemented zones can effectively define hydrocarbon migration pathways. More importantly, however, predictable relationships exist between the seismic expression of the HRDZs, the total amount of hydrocarbons that have leaked from the traps, and the obliquity between the Jurassic and Late Miocene fault trends over the respective structures. A continuum exists between highintegrity accumulations, in which the fault trends are parallel and the HRDZs are small or absent, and breached accumulations, in which a significant obliquity exists between the respective fault trends and the HRDZs are large and seismically-intense.These observations provide a potential predictive tool for evaluating undrilled structures. It may be possible to determine, from the integration of seismic structural mapping and the characterisation of the seismic expression of the HRDZs, not only whether an individual structure is ever likely to have had a hydrocarbon column, but whether that column is likely to be preserved.