Relevant bibliographies by topics / Structural traps (Petroleum geology)

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Academic literature on the topic 'Structural traps (Petroleum geology)'

Author: Grafiati
Published: 4 June 2021
Last updated: 28 January 2023

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Journal articles on the topic "Structural traps (Petroleum geology)"

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Zhou, Zhicheng, Wenlong Ding, Ruifeng Zhang, Mingwang Xue, Baocheng Jiao, Chenlin Wu, Yuting Chen, Liang Qiu, Xiaoyu Du, and Tianshun Liu. "Structural styles and tectonic evolution of Mesozoic–Cenozoic faults in the Eastern Depression of Bayanhaote Basin, China: implications for petroleum traps." Geological Magazine 159, no. 5 (January 20, 2022): 689–706. http://dx.doi.org/10.1017/s0016756821001242.

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AbstractThe Eastern Depression in the Bayanhaote Basin in western Inner Mongolia has experienced multi-stage Meso-Cenozoic tectonic events and possesses considerable exploration potential. However, structural deformation patterns, sequences and the genesis of oil-bearing structures in the basin are still poorly understood. In this study, based on high-quality 2D seismic data and drilling and well-logging data, we elucidate the activities and structural styles of faults, the tectonic evolution and the distribution characteristics of styles, as well as assessing potential petroleum traps in the Eastern Depression. Five types of faults that were active at different stages of the Meso-Cenozoic faults have been recognized: long-lived normal faults active since the late Middle Jurassic; reverse faults and strike-slip faults active in the late Late Jurassic; normal faults active in the Early Cretaceous; normal faults active in the Oligocene; and negative inverted faults active in the Early Cretaceous and Oligocene. These faults constituted 12 geometric styles in NE-trending belts at various stratigraphic levels, and were formed by compression, strike-slip, extension and inversion. The temporal development of structural styles promoted the formation and reconstruction and finalization of structural traps, while regional unconformities and open reverse and strike-slip faults provided migration pathways for petroleum to fill the traps. In general, potential traps that formed by compressional movement and strike-slip movement in the late Late Jurassic are primarily faulted anticlines. Those traps developed in Carboniferous rocks and are located in the southwestern region of the Eastern Depression, being controlled by NNE-NE-striking reverse and transpressive faults.
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Lambiase, J. J. "Structural Traps VII. Treatise of petroleum geology, Atlas of Oil and Gas Fields." Marine and Petroleum Geology 11, no. 2 (April 1994): 247. http://dx.doi.org/10.1016/0264-8172(94)90100-7.

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Terken, Jos M. J. "The Natih Petroleum System of North Oman." GeoArabia 4, no. 2 (April 1, 1999): 157–80. http://dx.doi.org/10.2113/geoarabia0402157.

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ABSTRACT The Cretaceous Natih petroleum system is one of the smaller petroleum systems in Oman, measuring only some 20,000 square kilometers in areal extent. Resource volumes of oil initially in-place, however, are significant and amount to 1.3x109 cubic meters (equivalent to 8.2 billion barrels). Most of the recoverable oil is concentrated in two giant fields that were discovered in the early 1960s. Since that prolific time no new major discoveries have been made, except some marginally economic accumulations in the early 1980s. To evaluate the remaining hydrocarbon potential of the system, the oil kitchen was mapped and its generation and migration histories modeled and integrated with the regional setting to outline the geographical and stratigraphical extent of the petroleum system. The volume of liquid hydrocarbons generated by Natih source rocks was calculated and compared to the estimated oil-in-place to determine the generation-trapping efficiency of the petroleum system. Some 100x109 cubic meters of source rock is currently mature and produced a cumulative volume of 14x109 cubic meters (88 billion barrels) oil. Of this volume 9% has actually been discovered and 0.25x109 cubic meters (1.57 billion barrels) are currently booked as recoverable reserves, equivalent to 1.8% of the total generated volume. Both percentages classify the Natih petroleum system as the most efficient system in Oman. This extreme efficiency results from several factors, such as: (1) modest structural deformation in the foreland basin, which permits lateral migration to remain the dominant style; (2) abundant and uninterrupted access to oil charge from an active kitchen in the foreland basin; and (3) excellent intra-formational source rocks, which is retained by thick Fiqa shales. Most structural prospects have been tested in four decades of exploration. The remaining hydrocarbon potential is anticipated to exist mainly in stratigraphic traps in Fiqa turbidites in the foreland basin, and truncation traps across the northern flank of the peripheral bulge.
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McLennan, Jeanette M., John S. Rasidi, Richard L. Holmes, and Greg C. Smith. "THE GEOLOGY AND PETROLEUM POTENTIAL OF THE WESTERN ARAFURA SEA." APPEA Journal 30, no. 1 (1990): 91. http://dx.doi.org/10.1071/aj89005.

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The northern Bonaparte Basin and the Arafura-Money Shoal Basins lie along Australia's offshore northern margin and offer significantly different exploration prospects resulting from their differing tectonic and burial histories. The Arafura Basin is dominated by a deep, faulted and folded, NW-SE orientated Palaeozoic graben overlain by the relatively flat-lying Jurassic-Tertiary Money Shoal Basin. The north-eastern Bonaparte Basin is dominated by the deep NE-SW orientated Malita Graben with mainly Jurassic to Recent basin-fill.A variety of potential structural and stratigraphic traps occur in the region especially associated with the grabens. They include tilted or horst fault blocks and large compressional, drape and rollover anticlines. Some inversion and possibly interference anticlines result from late Cenozoic collision between the Australian plate and Timor and the Banda Arc.In the Arafura-Money Shoal Basins, good petroleum source rocks occur in the Cambrian, Carboniferous and Jurassic-Cretaceous sequences although maturation is biassed towards early graben development. Jurassic-Neocomian sandstones have the best reservoir potential, Carboniferous clastics offer moderate prospects, and Palaeozoic carbonates require porosity enhancement.The Malita Graben probably contains good potential Jurassic source rocks which commenced generation in the Late Cretaceous. Deep burial in the graben has decreased porosity of the Jurassic-Neocomian sandstones significantly but potential reservoirs may occur on the shallower flanks.The region is sparsely explored and no commercial discoveries exist. However, oil and gas indications are common in a variety of Palaeozoic and Mesozoic sequences and structural settings. These provide sufficient encouragement for a new round of exploration.
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Suslova, Anna A., Antonina V. Stoupakova, Alina V. Mordasova, and Roman S. Sautkin. "Structural reconstructions of the Eastern Barents Sea at Meso-Tertiary evolution and influence on petroleum potential." Georesursy 23, no. 1 (March 30, 2021): 78–84. http://dx.doi.org/10.18599/grs.2021.1.8.

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Barents Sea basin is the most explored and studied by the regional and petroleum geologists on the Russian Arctic shelf and has approved gas reserves. However, there are many questions in the petroleum exploration, one of them is the structural reconstruction. During its geological evolution, Barents Sea shelf was influenced by the Pre-Novaya Zemlya structural zone that uplifted several times in Mesozoic and Cenozoic. The main goal of the research is to clarify the periods of structural reconstructions of the Eastern Barents shelf and its influence on the petroleum systems of the Barents Sea shelf. A database of regional seismic profiles and offshore borehole data collected over the past decade on the Petroleum Geology Department of the Lomonosov Moscow State University allows to define main unconformities and seismic sequences, to reconstruct the periods of subsidence and uplifts in Mesozoic and Cenozoic. The structural reconstructions on the Eastern Barents Sea in the Triassic-Jurassic boundary led to intensive uplifts and formation of the huge inversion swells, which is expressed in erosional truncation and stratigraphic unconformity in the Upper Triassic and Lower Jurassic strata. In the Jurassic period, tectonic subsidence reigned on the shelf, when the uplifts including the highs of Novaya Zemlya were partially flooded and regional clay seal and source rocks – Upper Jurassic «black clays» – deposited on the shelf. The next contraction phase manifested itself as a second impulse of the growth of inversion swells in the Late Jurassic-Early Cretaceous. Cenozoic uplift of the Pre-Novaya Zemlya structural zone and the entire Barents Sea shelf led to significant erosion of the Mesozoic sediments, on the one hand, forming modern structural traps, and on the other, significantly destroying the Albian, once regional seal.
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Selley, R. C. "E. A. Beaumont & N. H. Foster (compilers) 1990. Structural Traps I: Tectonic Fold Traps, x + 232 pp.; Structural Traps II: Traps Associated with Tectonic Faulting, xii + 267 pp.; Structural Traps III: Tectonic Fold and Fault Traps, x + 235 pp.; Structural Traps IV: Tectonic and Nontectonic Fold Traps, xii + 382 pp. American Association of Petroleum Geologists, Treatise of Petroleum Geology. Atlas of Oil and Gas Fields. Tulsa. Prices US $38, 38, 30, 39 respectively (hard covers). ISBNs 0 89181 850 5; 0 089181 581 3; 0 089181 583 X; 0 089181 584 8." Geological Magazine 128, no. 6 (November 1991): 678. http://dx.doi.org/10.1017/s001675680001983x.

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Vuong, Hoang Van, Tran Van Kha, Pham Nam Hung, and Nguyen Kim Dung. "Research on deep geological structure and forecasting of some areas with petroleum prospects in the Red river delta coastal strip according to geophysical data." Tạp chí Khoa học và Công nghệ biển 19, no. 3B (October 21, 2019): 71–89. http://dx.doi.org/10.15625/1859-3097/19/3b/14516.

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The coastal areas of the Red River Delta are the transition areas from the continent to the sea and have great mineral prospects, especially petroleum prospects. In this area, a lot of topics and projects in geology and geophysics have been conducted for many different purposes such as studying the deep structure, tectonic - geological features, seismic reflection - refraction to identify petroleum traps in the Cenozoic sediments... However there are very few studies on deep structure features, using the results of processing and meta-analysis of gravity, magnetotelluric, tectonic - geological data to detect the direct and indirect relations to the formation of structures with petroleum potential. The authors have researched, tested and applied an appropriate methodology of processing and analysis, to overcome the shortfall of gravity data as well as the nonhomogeneity in details of seismic and geophysical surveys. The obtained results are semi-quantitative and qualitative characteristics of structure of deep boundary surfaces, structural characteristics of fault systems and their distribution in the study area, calculation of the average rock density of pre-Cenozoic basement... From these results, the authors established the zoning map of the areas with petroleum potential in the Red river delta coastal strip according to geophysical data.
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Wender, Lawrence E., Jeffrey W. Bryant, Martin F. Dickens, Allen S. Neville, and Abdulrahman M. Al-Moqbel. "Paleozoic (Pre-Khuff Hydrocarbon Geology of the Ghawar Area, Eastern Saudi Arabia." GeoArabia 3, no. 2 (April 1, 1998): 273–302. http://dx.doi.org/10.2113/geoarabia0302273.

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ABSTRACT Saudi Aramco is conducting an exploration program to discover additional non-associated gas reserves in the Ghawar Area. The program has successfully discovered significant sweet gas and condensate reserves in the pre-Khuff siliciclastics and has further increased our understanding of the Paleozoic petroleum system. The Lower Permian Unayzah Formation is the principal pre-Khuff hydrocarbon reservoir in the Southern Ghawar Area, where it contains both oil and gas. The Unayzah consists of fluvial to marginal marine sandstones. The Devonian Jauf Formation is the principal pre-Khuff reservoir in the Northern Ghawar Area, where it hosts the recently discovered giant Hawiyah gas-condensate field. The Jauf consists of shallow marine sandstones that exhibit unusually high porosities considering the burial depths. The primary source rock for pre-Khuff hydrocarbons is the basal “hot shale” of the Lower Silurian Qalibah Formation. Maturation modeling of these shales indicates hydrocarbon generation began in the Middle Triassic (oil) and continues to the present (dry gas). Pre-Khuff hydrocarbon traps are found in simple four-way closures as well as more complex structural-stratigraphic traps on the flanks of Hercynian structures. Trap formation and modification occurred in four main phases: (1) Carboniferous (Hercynian Orogeny); (2) Early Triassic (Zagros Rifting); (3) Late Cretaceous (First or Early Alpine Orogeny); and (4) Tertiary (Second or Late Alpine Orogeny). Structures in the Ghawar Area show differences in growth histories, which have impacted the amount and type of hydrocarbons contained.
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Sapyanik, V. V., E. Yu Lapteva, E. V. Lyubutina, A. I. Nedospasov, P. I. Novikov, N. V. Petrova, A. V. Fateev, and A. P. Khilko. "GEODYNAMICS OF THE SEDIMENTARY COVER AND OIL-AND-GAS PROSPECTS OF THE TOMSK REGION EASTERN TERRITORY." Geology and mineral resources of Siberia, no. 3 (2021): 21–30. http://dx.doi.org/10.20403/2078-0575-2021-3-21-30.

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The article deals with geodynamic processes of the plicative tectonics of the Mesozoic-Cenozoic development stage in the southeastern territory of the West Siberian hemisyneclise, which allowed scientists to significantly clarify the configuration of multi-ordinal structures, to identify the second-order negative structure in the territory of the Baraba-Pikhtovka monocline, and to offer a new view of the structural-tectonic zoning of the Tomsk region eastern territory sedimentary cover. To substantiate the prospects of Jurassic petroleum plays, their resource potential is estimated using the basin modeling method. Based on an integrated analysis of structural imagings, history of the territory tectonic development, calculated maps of effective capacities, test results and WL conclusions, 42 traps of structural, structural-lithological, structural-stratigraphic types were mapped and their assessment by the volume-statistic method by Dl category [inferred resources] was given. The results obtained significantly expand the prospects for peripheral territories of the West Siberian Plate, where it is necessary to complete regional geological exploration.
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Abdullah, Rashed, Md Shahadat Hossain, Md Soyeb Aktar, Mohammad Moinul Hossain, and Farida Khanam. "Structural initiation along the frontal fold-thrust system in the western Indo-Burman Range: Implications for the tectonostratigraphic evolution of the Hatia Trough (Bengal Basin)." Interpretation 9, no. 3 (July 27, 2021): SF1—SF10. http://dx.doi.org/10.1190/int-2020-0227.1.

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The Bengal Basin accommodates an extremely thick Cenozoic sedimentary succession that derived from the uplifted Himalayan and Indo-Burman Orogenic Belts in response to the subduction of the Indian Plate beneath the Eurasian and Burmese Plates. The Hatia Trough is a proven petroleum province that occupies much of the southern Bengal Basin. However, the style of deformation, kinematics, and possible timing of structural initiation in the Hatia Trough and the relationship of this deformation to the frontal fold-thrust system in the outer wedge (namely, the Chittagong Tripura Fold Belt) of the Indo-Burman subduction system to the east are largely unknown. Therefore, we have carried out a structural interpretation across the eastern Hatia Trough and the western Chittagong Tripura Fold Belt based on 2D seismic reflection data. Our result suggests that the synkinematic packages correspond to the Pliocene Tipam Group and the Pleistocene Dupitila Formation. This implies that the structural development in the western Chittagong Tripura Fold Belt took place from the Pliocene. In the Hatia Trough, the timing of structural activation is slightly later (since the Plio-Pleistocene). In general, fold intensity and structural complexity gradually increase toward the east. The presence of reverse faults with minor strike-slip motion along the frontal thrust system in the outer wedge is also consistent with the regional transpressional structures of the Indo-Burman subduction system. However, to the west, there is no evidence for strike-slip deformation in the Hatia Trough. The restored sections indicate that the amount of east–west shortening in the Hatia Trough is very low (maximum 1.2%). In contrast, to the east, the amount of shortening is high (maximum 13.5%) in the western margin of the Chittagong Tripura Fold Belt. In both areas, the key trapping mechanism includes anticlinal traps, although stratigraphic and combinational traps are possible, but this requires further evaluation.
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Dissertations / Theses on the topic "Structural traps (Petroleum geology)"

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Qi, Fazheng. "Structural styles of the Jeanne d'Arc basin, Grand Banks, offshore Newfoundland, and their implication for petroleum exploration." Thesis, McGill University, 1989. http://digitool.Library.McGill.CA:80/R/?func=dbin-jump-full&object_id=61796.

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Ahanor, David. "Integrated Reservoir Modelling of the Norne Field. : Volume Visualization/Seismic Attribute,Structural and Property Modeling." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for geologi og bergteknikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-20379.

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ABSTRACT The purpose of this thesis project work is to build reservoir models (structural, facies and Petrophysical property models) of the different reservoir surfaces using integrated data sets (seismic, wells, fault sticks, eclipse models, horizon surfaces) of the Norne field which is located in blocks 6608/10 and 6508/1 in the southern part of the Nordland II area. Different visualizations techniques, volume rendering and seismic attributes were applied to aid the seismic interpretation and to provide detailed evaluation/integration of the data. 3D seismic interpretation for the whole seismic volume within the reservoir section was done manually with controlled input surfaces/reflectors of the Top horizons of the Not and Åre Formations. Fault and surfaces interpretation of the reservoir were generated as key inputs in the modeling process The structural 3D grid skeleton and models were generated with critical inputs of the manually interpreted faults/horizons, using different qualitative/quantitative templates in Petrel. This was followed by well interpretation and upscaling to provide discrete facies which are needed in populating the structural models of each of the reservoir surfaces. A probabilistic facies model was done to capture the proportion of the spatial dimensions of each discrete facies in the model frame. The initiation of this study involves quantitative data quality controls and management of inputs files into the Petrel window, qualitative control involves transferring geologic licenses/understanding to the various interpretations in the visualization schemes, seismic interpretation and reservoir modeling templates. The combination of different data type and idea (volumes, wells, top surfaces, and fault sticks) types means that the user must have a multivariate understanding (Geologic, Geophysical, Petrophysical, Geostastistic, Geo-Modeling and Reservoir Engineering) in other to integrate the data sets and deliver the models. Eleven wells were used in reference to the Top surface of the Not, Åre Top surfaces and Statoil Reference report of the field, to deliver and control the seismic interpretation. A wedge shape structure was observed in the reservoir section. Typically, minor and major faults were interpreted as forming compartments in the reservoir, which were interpreted across the different lines. The structural framework in the field was largely defined by the Norne Horst and associated faults, with the erosional surface of the BCU with internal sub unconformities observed. The property facies model of the reservoir surfaces (Garn, Ile, Tofte, and TIlje) suggest that the Norne Horst and sub relief structures are mainly sand rich, which provides additional prospect indicators in exploring the field
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Catterall, Jeffrey John. "Structural Framework of the Statfjord Formation (Rhaetian-Sinemurian) in the Oseberg South Field, Norwegian North Sea." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for geologi og bergteknikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-20095.

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The Statfjord Formation (Rhaetian-Sinemurian) produces from six fields across the North Sea, but no discoveries have yet been made in the 12 exploration wells across the Oseberg South Field. The field has undergone two major periods of rifting in the Permian-Triassic and from the mid-Jurassic to Early Cretaceous. The Statfjord Formation was deposited during the Permian-Triassic post-rift period, but its tectonic influence on the paleogeography of the formation is not well understood. An isopach map produced from seismic interpretation and RMS modelling of the Statfjord Formation showed a westward thickening trend towards the present-day Viking Graben. This study presents results obtained using new, high-quality OBC seismic data that has allowed for faults throughout the field to be mapped in great detail. Supported by stratigraphic correlations and biostratigraphy, the mapping has showed that most faults can be assigned to either of the main rifting phases or their associated post-rift subsidence histories. Large, east-dipping faults are believed to have originated during the Permo-Triassic rifting, with evidence of movement into the Cretaceous. Large thickness increases of the formation over the westward dipping Oseberg and Brage Faults, as well as syn-rift sediments within some grabens in the J structure indicate movements of these faults during deposition. Biostratigraphic data show that the lowermost part of the Statfjord Formation was approximately the same thickness across the field until the Late Triassic, constraining the initiation of the Oseberg and Brage Faults to the Early Jurassic. Interpretations from timelines correlated within the Statfjord Formation suggest that the rate of subsidence along different faults was not consistent through time. Thickness changes along strike of the fault indicate that the movement along the fault was diachronous. This study aims to show that major fault activity influenced the deposition, and possibly preservation potential of sediment in the Statfjord Formation. The second phase of rifting is believed to have initiated many of the faults within the field, as well as reactivated the Oseberg and Brage Faults. Additional NW-SE faults in the Omega structure show no evidence of syn-rift sediments at the Statfjord Formation level, suggesting a mid-Jurassic post-rift origin. Similarly oriented faults were seen in the C structure, however, the presence of syn-rift sediments was difficult to ascertain, and no conclusions about the timing of initiation were made.
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Kaenmee, Kwanjai. "Structural Interpretation and Investigation of the Displacement Gradients of the Normal Fault System beneath the Horda Platform, the northern North Sea." Thesis, Norges teknisk-naturvitenskapelige universitet, Institutt for petroleumsteknologi og anvendt geofysikk, 2012. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-19211.

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The North Sea basin is one of the best-studied areas in the world with respect to thestructural and sedimentary architecture of rift zones. The Base Cretaceous Unconformity,which defines a mappable horizon at the transition from synrift to postrift sequencesassociated with the Jurassic–Cretaceous rift, is well known as a reference marker for bothseismic and well log interpretations and covers most of the basin. This unconformity isinterpreted at the locations of the Øygarden Fault Zone, the Troll Fault Block, the NorthViking Graben, the Tampen Spur, the Snorre Fault Block, the Sogn Graben and the HordaPlatform. The complexities of the unconformity have been established and vary with thestructural and geographical position within the basin. However, as the Base CretaceousUnconformity covers most of the northern North Sea, its structural time map, is used to derivethe picture of post-structural framework of a rift basin and to locate essential structures in thedeeper sections.Three main reflectors (Pre-Jurassic 1, Pre-Jurassic 2 and Top seismic basement)located beneath the Base Cretaceous Unconformity on the Horda Platform, and have beeninterpreted using 2D seismic reflection data. These three reflectors have been studied in orderto investigate in detail the displacement gradients and possible linkage of the early faultsystem under the Horda Platform, and to evaluate their effect on the large-scale sedimentarchitecture. A main reason to work on the structures under the Horda Platform is due to thefact that these structures are believed to have existed already in the early stages of thenorthern North Sea basin development.The extensional normal fault systems of both the Permo-Triassic and the Late Jurassicrifts are considered a key control on the geological structures and sedimentary architecture ofthe region as presently seen. The basin evolution related Permo-Triassic rifting is mostpronounced on the eastern part of the Horda platform where its synrift geometry is obviouslyseen with the huge segment length and largest uplift explainable by a flexural stretchingmodel. The rift axis is transferred to position at base of the Viking graben during the Late-Jurassic rifting with the smaller magnitude of extension than the Permo-Triassic as clearlyseen by the less thickness of the synrift geometry. However, the structural evolution of normalfaults and the basin architecture under the Horda Platform is particularly affected by thecomplex interaction of fault linkage, fault propagation, fault growth, and death of faultthrough times from the early stage to the final stage of the basin development. Apart from theeffects of major tectonic controls, additionally, non-tectonic parameters, such as climate, seaor lake level changes, and differences in amount and type of sediment supply, should be takeninto account to influence the stratigraphic and sedimentation patterns in the basin.
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Floyd, Julie. "SUBSURFACE GEOLOGICAL ANALYSES OF THE BEREA PETROLEUM SYSTEM IN EASTERN KENTUCKY." UKnowledge, 2015. http://uknowledge.uky.edu/ees_etds/33.

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The Berea Sandstone is a Late Devonian, tight oil and gas reservoir that intertongues with the Bedford Shale in eastern Kentucky. In order to evaluate the Bedford-Berea interval in the subsurface, 555 well logs from the Kentucky Geological Survey’s oil and gas database were used to construct structure maps, isopach maps, and cross sections of the interval and its possible hydrocarbon source rocks. Gamma-ray logs were compared to known cores in order to separate Bedford from Berea lithologies. Maps and cross sections were compared to known basement structures to evaluate possible structural influences on the interval. The Bedford-Berea interval is thickest along a north-south elongate trend which extends from Lewis to Pike Counties and cuts across basement structures. Along this trend, the interval is thickest and the percentage of Berea lithologies is greatest on known basement highs. The interval is thinnest and dominated by Bedford shales above structural lows and west of the main trend. Several wells are also reported in which the Bedford-Berea thickens on the down-thrown side of major faults. Also, in northeastern Kentucky, where the Berea is thickest, possible submarine channel facies are identified which cut into the underlying Cleveland Shale near the Waverly Arch.
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Smith, Stuart A. "The phanerozoic basin-fill history of the Roebuck Basin /." Title page, abstract and contents only, 1999. http://web4.library.adelaide.edu.au/theses/09PH/09phs6615.pdf.

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Indrelid, Jarand. "Stratigraphy, structural geology and petroleum potential of Cretaceous and Tertiary rocks in the central Graham Island area, Queen Charlotte Islands, British Columbia." Thesis, University of British Columbia, 1991. http://hdl.handle.net/2429/29881.

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Mapping at 1:25 000 scale on the central Graham Island has shown that Cretaceous strata are more widely distributed than previously known. This study examines the stratigraphy and structural geology of the Cretaceous rock sequence, and also addresses the petroleum potential of these units. At the base is the Cretaceous sandstone unit. This unit is divided into three lithofacies. The massive sandstone lithofacies is a coarse grained, dark green to greenish black, massive sandstone. Parts of this lithofacies contains up to 50 % glauconite. The grey sandstone lithofacies is finer grained and has better defined bedding than the massive sandstone. It is frequently found with interlayered sandstone, siltstone, and shale. The third sandstone lithofacies is characterized by pervasive bioturbation. All three lithofacies are texturally immature, contain angular quartz and feldspar, and are rich in chlorite clay. The Cretaceous sandstone unit is interpreted as a transgressive sequence deposited on a storm dominated shelf. Conformably overlying the sandstones are the massive friable shale and silty shale of the Cretaceous shale unit. Intervals with increased input of storm generated sandstone layers are found throughout the unit. Spherical and elliptical calcareous concretions up to over 1 m across are common. The Cretaceous shale unit represent a continuation of marine transgression with deepening of the sedimentary basin. Turbidites forming the Skidegate Formation are interbedded with the upper part of the shale unit. This formation consists of interbedded shale, siltstone, and fine grained sandstone. Sedimentary structures are often well developed on bedding surfaces. The rocks of this unit are distal turbidites and levee deposits of a submarine fan. Coarse clastic rocks of the Honna Formation are interbedded with the Skidegate Formation. This formation is dominated by pebbly conglomerates and coarse grained sandstones. The clast material in the conglomerate lithofacies is mainly derived from units present on the islands. The sandstone lithofacies consists of indurated, bluish, medium- to coarse-grained sandstone. This formation is richer in quartz and biotite than any other Cretaceous sandstones of the central Graham Island. The Honna and Skidegate formations are the result of deposition from a submarine fan system that was initiated in Late Cretaceous time. Deposition of shale continued after the deposition of the submarine fan-related formations terminated. The Cretaceous rock sequence is overlain by Tertiary volcanic and sedimentary rocks. Volcanic rocks occur throughout the area, and sediments of the Skonun Formation are exposed in north. Three major periods of deformation are recorded in the Cretaceous units. The first event was a Late Cretaceous to Early Tertiary northeast directed compression, resulting in northwest trending folds and thrust faults. The deformation was highly localized to areas were weakness zones existed in the older basement rocks. Two periods of Tertiary block faulting activity are recognized. The first resulted in northwest-trending faults, parallel to older structures. Later Tertiary block faulting developed northeast trending faults, which are the youngest macroscopic structures in the area. The Cretaceous rock sequence does not contain any promising hydrocarbon source or reservoir rocks. The TOC, S1, and S2 values from Rock-Eval® pyrolysis are low for all units, and the organic material present is mostly gas prone. Visual porosity is generally poor, as a result of chlorite pore-filling clay and calcite cement.
Science, Faculty of
Earth, Ocean and Atmospheric Sciences, Department of
Graduate
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Morrison, William F. "Vertical and Lateral Hydraulic Connectivity of the Wilcox Formation for Tiber Field and the Outbound Structural Province of Keathley Canyon and Walker Ridge, Northern Gulf of Mexico." ScholarWorks@UNO, 2018. https://scholarworks.uno.edu/td/2569.

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Hydraulic connectivity for the Tiber field and 17 other Wilcox penetrations in Keathley Canyon (KC) and 5 fields in Walker Ridge (WR) protraction areas was assessed. All five chronostratigraphic Wilcox units are not in vertical communication across both protraction areas. Four of these units are in lateral communication across Tiber field except where faults isolate portions of the structure. Five “areas of connectivity,” where two or more fields are in communication, were found in KC. The fields in WR show no evidence of connectivity despite a relatively simpler structural environment than KC. I propose that the wells in WR are isolated due to a combination of diagenetic cementation and increased vertical effective stress acting to decrease permeability between structures. I also attempted to assess the possibility of hydrodynamic flow in the primary basin encompassing Tiber by geophysically identifying the field’s oil water contact and determining its orientation. This was unsuccessful.
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Benvenutti, Carlos Felipe [UNESP]. "Estudo da porção offshore da bacia do Benin e o seu potencial no armazenamento de hidrocarbonetos, margem equatorial africana." Universidade Estadual Paulista (UNESP), 2012. http://hdl.handle.net/11449/92925.

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Made available in DSpace on 2014-06-11T19:26:14Z (GMT). No. of bitstreams: 0 Previous issue date: 2012-04-20Bitstream added on 2014-06-13T18:47:38Z : No. of bitstreams: 1 benvenutti_cf_me_rcla.pdf: 5702564 bytes, checksum: 3468aeafad128f8380c10b5ae674509f (MD5)
A presente pesquisa conta com uma área de estudo de 7.737 km2 na porção ojJshore da Bacia do Benin, localizada na Província do Golfo da Guiné, Margem Equatorial Africana, onde a lâmina da água varia de 100 a mais de 3.200 m, cobrindo basicamente o talude. Dados ísmicos 3D e 2D foram disponibilizados pela Compagnie Béninoise des Hydrocarbures(CBH SARL) para interpretação dos mesmos com o objetivo de caracterizar o arcabouço estrutural e estratigráfico da região, assim como avaliar o potencial do armazenamento de hidrocarboneto. Foi necessário o mapeamento dos horizontes sísmicos, a elaboração de mapas de contorno estrutural, de atributos sísmicos e de isópacas. A Bacia do Benin encontra-se entre as zonas de fratura de Romanche e Chain, correlata à Bacia do Ceará na Margem Equatorial Brasileira. Sua evolução tectono-sedimentar está condicionada à ruptura do Gondwana no Cretáceo Inferior, predominando estruturas da fase rifte relacionadas à distensão e transcorrência, a influência da transpressão é muito significativa no Cretáceo Superior. Destaca-se também uma tectônica gravitacional marcada por falhamentos dos níveis estratigráficos cenozóicos. A coluna sedimentar é representada por uma seção rifte continental limitada pela discordância do Meso-Albiano e outra pós-rifte marinha, do Albiano Superior ao Recente; sendo esta subdividida pela discordância do Oligoceno relacionada a uma queda eustática. A sedimentação está controlada pelo strends NE-SW e ENE-WSW, incluindo os canais submarinos. Os principais altos estruturais desta região já foram perfurados sem sucesso comercial, porém o potencial de acumulação de hidrocarbonetos é promissor, pelo menos dois grandes canais foram identificados no estudo em uma região cuja profundidade do fundo do mar é cerca de 2.200 m. Oportunidades...
The present research has a study area of 7.737 km2 located in the offshore portion of Benin Basin in the Gulf of Guinea Province, African Equatorial Margin. The water depth ranges from 100 to more than 3.200 m, basically covering the slope. The Compagnie Béninoise des Hydrocarbures (CBH SARL) provided 3D and 2D seismic data in order to interpret and characterize the stratigraphic and structural frarnework, as well as to evaluate the petroleum exploration potential. To achieve the desired results, it was performed seismic horizons mapping, elaboration of structural outline, isopach and seismic attribute maps. Benin Basin is limited by Romanche and Chain fracture zones and is correlated to Ceará Basin in Brazilian Equatorial Margin. Its tectono-stratigraphic evolution was conditioned by the Gondwana break-up in the Lower Cretaceous and shows rift structures related to extension trike-slip tectonics. The transpression influence is very significant in the Upper Cretaceous. It is also highlighted a gravitational tectonic marked by normal faults in the Cenozoic level. The sedimentary package is represented by a continental rift section limited by a Mid-Albian unconformity and other marine post-rift sequence from Upper Albian to Recent; the last one can still be divided by the Oligocene unconformity. The sedimentation is controlled by NE-SW and ENE- WSW trends, including submarine channels in the Upper Cretaceous. The main structural traps weredrilled in the study area without commercial success. At least two great channels were identified in a region where the water depth is around 2.200 m. Roll-overs and minor channels opportunities in Paleogene and Neogene should also be considered. The pre-rift sequences of the study area are poorly recognized, the absence of well information in this interval and the low resolution of seismic data... (Complete abstract click electronic access below)
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Benvenutti, Carlos Felipe. "Estudo da porção offshore da bacia do Benin e o seu potencial no armazenamento de hidrocarbonetos, margem equatorial africana /." Rio Claro : [s.n.], 2012. http://hdl.handle.net/11449/92925.

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Resumo: A presente pesquisa conta com uma área de estudo de 7.737 km2 na porção ojJshore da Bacia do Benin, localizada na Província do Golfo da Guiné, Margem Equatorial Africana, onde a lâmina da água varia de 100 a mais de 3.200 m, cobrindo basicamente o talude. Dados ísmicos 3D e 2D foram disponibilizados pela Compagnie Béninoise des Hydrocarbures(CBH SARL) para interpretação dos mesmos com o objetivo de caracterizar o arcabouço estrutural e estratigráfico da região, assim como avaliar o potencial do armazenamento de hidrocarboneto. Foi necessário o mapeamento dos horizontes sísmicos, a elaboração de mapas de contorno estrutural, de atributos sísmicos e de isópacas. A Bacia do Benin encontra-se entre as zonas de fratura de Romanche e Chain, correlata à Bacia do Ceará na Margem Equatorial Brasileira. Sua evolução tectono-sedimentar está condicionada à ruptura do Gondwana no Cretáceo Inferior, predominando estruturas da fase rifte relacionadas à distensão e transcorrência, a influência da transpressão é muito significativa no Cretáceo Superior. Destaca-se também uma tectônica gravitacional marcada por falhamentos dos níveis estratigráficos cenozóicos. A coluna sedimentar é representada por uma seção rifte continental limitada pela discordância do Meso-Albiano e outra pós-rifte marinha, do Albiano Superior ao Recente; sendo esta subdividida pela discordância do Oligoceno relacionada a uma queda eustática. A sedimentação está controlada pelo strends NE-SW e ENE-WSW, incluindo os canais submarinos. Os principais altos estruturais desta região já foram perfurados sem sucesso comercial, porém o potencial de acumulação de hidrocarbonetos é promissor, pelo menos dois grandes canais foram identificados no estudo em uma região cuja profundidade do fundo do mar é cerca de 2.200 m. Oportunidades... (Resumo completo, clicar acesso eletrônico abaixo)
Abstract: The present research has a study area of 7.737 km2 located in the offshore portion of Benin Basin in the Gulf of Guinea Province, African Equatorial Margin. The water depth ranges from 100 to more than 3.200 m, basically covering the slope. The Compagnie Béninoise des Hydrocarbures (CBH SARL) provided 3D and 2D seismic data in order to interpret and characterize the stratigraphic and structural frarnework, as well as to evaluate the petroleum exploration potential. To achieve the desired results, it was performed seismic horizons mapping, elaboration of structural outline, isopach and seismic attribute maps. Benin Basin is limited by Romanche and Chain fracture zones and is correlated to Ceará Basin in Brazilian Equatorial Margin. Its tectono-stratigraphic evolution was conditioned by the Gondwana break-up in the Lower Cretaceous and shows rift structures related to extension trike-slip tectonics. The transpression influence is very significant in the Upper Cretaceous. It is also highlighted a gravitational tectonic marked by normal faults in the Cenozoic level. The sedimentary package is represented by a continental rift section limited by a Mid-Albian unconformity and other marine post-rift sequence from Upper Albian to Recent; the last one can still be divided by the Oligocene unconformity. The sedimentation is controlled by NE-SW and ENE- WSW trends, including submarine channels in the Upper Cretaceous. The main structural traps weredrilled in the study area without commercial success. At least two great channels were identified in a region where the water depth is around 2.200 m. Roll-overs and minor channels opportunities in Paleogene and Neogene should also be considered. The pre-rift sequences of the study area are poorly recognized, the absence of well information in this interval and the low resolution of seismic data... (Complete abstract click electronic access below)
Orientador: Nelson Angeli
Coorientador: Maria Gabriela C. Vincetelli
Banca: George Luiz Luvizotto
Banca: Adilson Viana Soares Júnior
Mestre
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Books on the topic "Structural traps (Petroleum geology)"

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Beaumont, E. A. Structural traps. Tulsa, Okla., U.S.A: American Association of Petroleum Geologists, 1992.

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Beaumont, E. A. Structural traps. Tulsa, Okla., U.S.A: American Association of Petroleum Geologists, 1990.

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Beaumont, E. A. Structural traps. Tulsa, Okla., U.S.A: American Association of Petroleum Geologists, 1990.

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H, Foster Norman, ed. Structural traps. Tulsa, Okla., U.S.A: American Association of Petroleum Geologists, 1990.

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P, Coward M., Daltaban T. S, and Johnson H, eds. Structural geology in reservoir characterization. London: Geological Society, 1998.

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Bearden, Bennett L. Seismic expression of structural style and hydrocarbon traps in the Norphlet Formation, offshore Alabama. Tuscaloosa, Ala: Geological Survey of Alabama for the State Oil and Gas Board, 1987.

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SEPM Core Workshop (18th 1993 New Orleans, La.). Paleokarst related hydrocarbon reservoirs: SEPM Core Workshop No. 18, New Orleans, April 25, 1993. Tulsa, Okla: SEPM, 1993.

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Thrust fault-related folding. Tulsa, OK: American Association of Petroleum Geologists, 2011.

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H, Foster Norman, and Beaumont E. A, eds. Traps and seals. Tulsa, Okla, U.S.A: American Association of Petroleum Geologists, 1988.

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H, Foster Norman, ed. Stratigraphic traps. Tulsa, Okla., U.S.A: American Association of Petroleum Geologists, 1990.

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Book chapters on the topic "Structural traps (Petroleum geology)"

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Khomsi, Sami, Francois Roure, Najoua Ben Brahim, Chokri Maherssi, Mohamed Arab, and Mannoubi Khelil. "Structural Styles, Petroleum Habitat and Traps in the Pelagian-Sirt Basins, Northern Africa: An Overview and Future Exploration Developments." In The Structural Geology Contribution to the Africa-Eurasia Geology: Basement and Reservoir Structure, Ore Mineralisation and Tectonic Modelling, 159–62. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-030-01455-1_33.

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Mahoney, John J. "Deccan Traps." In Petrology and Structural Geology, 151–94. Dordrecht: Springer Netherlands, 1988. http://dx.doi.org/10.1007/978-94-015-7805-9_5.

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Zolotukhin, V. V., and A. I. Al’mukhamedov. "Traps of the Siberian Platform." In Petrology and Structural Geology, 273–310. Dordrecht: Springer Netherlands, 1988. http://dx.doi.org/10.1007/978-94-015-7805-9_8.

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Jia, Chengzao. "Main Types of Petroleum Reservoir and Characteristics of Oil and Gas Traps." In Characteristics of Chinese Petroleum Geology, 153–80. Berlin, Heidelberg: Springer Berlin Heidelberg, 2012. http://dx.doi.org/10.1007/978-3-642-23872-7_4.

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Lirong, Dou, and Li Jinchao. "Structural Style and Petroleum Systems of the Songliao Basin." In Geology of Fossil Fuels - Oil and Gas, 33–42. London: CRC Press, 2021. http://dx.doi.org/10.1201/9780429087837-4.

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Adouani, Ferid, Ahmed Saadi, Francis Chevalier, and Noura Ayari. "South Tunisia, Structures and Traps Evolution: A Review from a New 3D Mega-Merge Survey." In The Structural Geology Contribution to the Africa-Eurasia Geology: Basement and Reservoir Structure, Ore Mineralisation and Tectonic Modelling, 175–77. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-030-01455-1_37.

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Arab, Mohamed, Mohamed Hassaim, Chokri El Maherssi, Karim Belabed, and François Roure. "Insight into the Tectonics of the Kaboudia Area and Related Petroleum Systems, Eastern Tunisian Offshore (Tunisia)." In The Structural Geology Contribution to the Africa-Eurasia Geology: Basement and Reservoir Structure, Ore Mineralisation and Tectonic Modelling, 153–57. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-030-01455-1_32.

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Surjono, Sugeng Sapto, Muhamad Rizki Asy’ari, and Arif Gunawan. "Petroleum Play Potential in the Thrust and Fold Belt Zone of the Offshore Timor-Tanimbar, Eastern Indonesia." In The Structural Geology Contribution to the Africa-Eurasia Geology: Basement and Reservoir Structure, Ore Mineralisation and Tectonic Modelling, 145–48. Cham: Springer International Publishing, 2018. http://dx.doi.org/10.1007/978-3-030-01455-1_30.

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Allison, Iain. "A structural study of north sea petroleum traps using hypercard." In Structural Geology and Personal Computers, 43–50. Elsevier, 1996. http://dx.doi.org/10.1016/s1874-561x(96)80007-1.

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Selley, Richard C., and Stephen A. Sonnenberg. "Traps and Seals." In Elements of Petroleum Geology, 321–75. Elsevier, 2015. http://dx.doi.org/10.1016/b978-0-12-386031-6.00007-2.

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Conference papers on the topic "Structural traps (Petroleum geology)"

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Guevara, Jose Manuel, Mary Grace Jubb, Abdulla Seliem, Hilario Camacho, and Jorge Mario Lozano. "Development, Evolution, and Episodic Charge History of Pop-up Structures in Southeast Abu Dhabi, UAE." In Abu Dhabi International Petroleum Exhibition & Conference. SPE, 2021. http://dx.doi.org/10.2118/207761-ms.

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Abstract The main goal of this paper is contributing to the understanding to the structural geology, development, and evolution of traps associated with strike-slip restraining bend and restraining step-over structures as a key petroleum system element in southeastern Abu Dhabi. We introduce a preliminary classification scheme for these relatively small, low-relief features defined here as pop-up structures. These structures represent different evolutionary stages of strike-slip restraining bends formed along prominent WNW-trending strike-slip fault systems in southeastern Abu Dhabi. The proposed classification scheme was summarized as a chart to illustrate the correlation between the degree of structural deformation and seal integrity, and estimates the likelihood of finding multiple, vertically stacked, productive reservoirs. It also leads to a more detailed discussion on others important characteristics of pop-up structures and provides a better understanding of sealing mechanisms such as fault juxtaposition, fault throw analysis, fault slip tendency, fault rock processes, and the role of the development of hybrid flower structures in the area. We will also show a simple case study based on two exploratory wells that targeted two pop-up structures with different degrees of deformation in southeast Abu Dhabi. This case study illustrates the complex relationship between pop-up evolution, timing of trap formation, seal integrity, trap preservation, and multiple petroleum generation and migration events. Pop-up structures are linked to multiple episodes of trap and seal evolution, where several episodes of hydrocarbon migration, charge, and leaking of hydrocarbons may occur.
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Witte, Jan, Daniel Trümpy, Jürgen Meßner, and Hans Georg Babies. "Petroleum Potential of Rift Basins in Northern Somalia – A Fresh Look." In SPE/AAPG Africa Energy and Technology Conference. SPE, 2016. http://dx.doi.org/10.2118/afrc-2573746-ms.

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ABSTRACT Several wells have encountered good oil shows in the rift basins of northern Somalia, however, without finding commercial hydrocarbons to date. It is widely accepted that these basins have a similar tectonic evolution and a comparable sedimentary fill as the highly productive rift basins in Yemen from which they have been separated by the opening of the Gulf of Aden (fully established in Mid Oligocene). We present new regional tectonic maps, new basement outcrop maps, a new structural transect and new play maps, specifically for the Odewayne, Nogal, Daroor and Socotra Basins. Digital terrain data, satellite images, surface geology maps (varying scales), oil seep/slick maps, potential data (gravity), well data from ~50 wells and data from scientific publications were compiled into a regional GIS-database, so that different data categories could be spatially analyzed. To set the tectonic framework, the outlines of the basins under investigation were re-mapped, paying particular attention to crystalline basement outcrops. A set of play maps was established. We recognize at least three source rocks, five reservoirs and at least three regional seals to be present in the area (not all continuously present). Numerous oil seeps are documented, particularly in the Nogal and Odewayne Basins, indicative of ongoing migration or re-migration. Data from exploration wells seem to further support the presence of active petroleum systems, especially in the central Nogal, western Nogal and central Daroor Basins. Our GIS-based data integration confirms that significant hydrocarbon potential remains in the established rift basins, such as the Nogal and Daroor Basins. Additionally, there are a number of less known satellite basins (on and offshore) which can be mapped out and that remain completely undrilled. All of these basins have to be considered frontier basins, due to their poorly understood geology, remoteness, marketing issues and missing oil infrastructure, making the economic risks significant. However, we believe that through acquisition of new seismic data, geochemical analysis, basin modelling and, ultimately, exploration drilling these risks can be mitigated to a point where the economic risks become acceptable. We encourage explorers to conduct regional basin analysis, data integration, a GIS-based approach and modern structural geology concepts to tackle key issues, such as trap architecture, structural timing, migration pathways and breaching risks.
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Al Anboori, Abdullah, Stephen Dee, Khalil Al Rashdi, and Herbert Volk. "De-Risking Fluid Compartmentalization of the Barik Reservoir in the Khazzan Field, Oman - An Integrated Approach." In Abu Dhabi International Petroleum Exhibition & Conference. SPE, 2021. http://dx.doi.org/10.2118/207687-ms.

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Abstract The degree of fluid compartmentalization has direct implications on the development costs of oil and gas reservoirs, since it may negatively impact gas water contacts (GWC) and fluid condensate gas ratios (CGR). In this case study on the Barik Formation in the giant Khazzan gas field in Block 61 in Oman we demonstrate how integrating independent approaches for assessing potential reservoir compartmentalization can be used to assess compartmentalization risk. The three disciplines that were integrated are structural geology (fault seal analysis, movement and stress stages of faults and fractures, traps geometry over geological time), petroleum systems (fluid chemistry and pressure, charge history) and sedimentology-stratigraphy including diagenesis (sedimentological and diagenetic controls on vertical and lateral facies and reservoir quality variation). Dynamic data from production tests were also analyzed and integrated with the observations above. Based on this work, Combined Common Risk Segment (CCRS) maps with a most likely and alternative scenarios for reservoir compartmentalization were constructed. While pressure data carry significant uncertainty due to the tight nature of the deeply buried rocks, it is clear pressures in gas-bearing sections fall onto a single pressure gradient across Block 61, while water pressures indicate variable GWCs. Overall, the GWCs appear to shallow across the field towards the NW, while water pressure appears to increase in that direction. The "apparent" gas communication with separate aquifers is difficult to explain conventionally. A range of scenarios for fluid distribution and reservoir connectivity are discussed. Fault seal compartmentalization and different trap spill points were found to be the most likely mechanism explaining fluid distribution and likely reservoir compartmentalization. Perched water may be another factor explaining variable GWCs. Hydrodynamic tilting due to the flow of formation water was deemed an unlikely scenario, and the risk of reservoir compartmentalization due to sedimentological and diagenetic flow barriers was deemed to be low.
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Carrasco, Javier. "Methodology of the Juxtaposition Analysis for Fault Structural Traps." In SPE Latin America and Caribbean Petroleum Engineering Conference. Society of Petroleum Engineers, 2012. http://dx.doi.org/10.2118/152021-ms.

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Biteau, J. J., A. le Marrec, M. le Vot, and J. M. Masset. "The Aquitaine Basin, Stratigraphic and Structural History, Petroleum Geology." In 2nd EAGE St Petersburg International Conference and Exhibition on Geosciences. European Association of Geoscientists & Engineers, 2006. http://dx.doi.org/10.3997/2214-4609-pdb.20.a007.

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Pettinelli, R. "Campano-Lucano Apennine Sector - Allochtonous Sheets Structural Setting." In EAGE Conference on Geology and Petroleum Geology of the Mediterranean and Circum-Mediterranean Basins. European Association of Geoscientists & Engineers, 2000. http://dx.doi.org/10.3997/2214-4609.201406014.

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Hofmann, C. "Wajid Graben Structural Evolution." In Seventh Arabian Plate Geology Workshop: Pre-Cambrian to Paleozoic Petroleum Systems in the Arabian Plate. Netherlands: EAGE Publications BV, 2018. http://dx.doi.org/10.3997/2214-4609.201900210.

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Khomsi, S., M. M. Turki, H. Zouari, and D. Turki. "Structural Inheritance and Tectono-Sedimentary Analysis in Amdoun Zone, North Tunisia." In EAGE Conference on Geology and Petroleum Geology of the Mediterranean and Circum-Mediterranean Basins. European Association of Geoscientists & Engineers, 2000. http://dx.doi.org/10.3997/2214-4609.201406049.

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Sciamanna, S., R. Gambini, F. Mosca, C. Nicolai, J. L. Rudkiewicz, and W. Sassi. "The Southern Apennine Thrust Belt - Forward Structural and Geochemical Modelling Since Messinian Times." In EAGE Conference on Geology and Petroleum Geology of the Mediterranean and Circum-Mediterranean Basins. European Association of Geoscientists & Engineers, 2000. http://dx.doi.org/10.3997/2214-4609.201405992.

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Goucem, N., and N. Abdelouahab. "Structural Evolution, Source Rock Thermal History and Hydrocarbons Generation in the Berkine Basin." In EAGE Conference on Geology and Petroleum Geology of the Mediterranean and Circum-Mediterranean Basins. European Association of Geoscientists & Engineers, 2000. http://dx.doi.org/10.3997/2214-4609.201406039.

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Reports on the topic "Structural traps (Petroleum geology)"

1

Lacerda Silva, P., G. R. Chalmers, A. M. M. Bustin, and R. M. Bustin. Gas geochemistry and the origins of H2S in the Montney Formation. Natural Resources Canada/CMSS/Information Management, 2022. http://dx.doi.org/10.4095/329794.

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The geology of the Montney Formation and the geochemistry of its produced fluids, including nonhydrocarbon gases such as hydrogen sulfide were investigated for both Alberta and BC play areas. Key parameters for understanding a complex petroleum system like the Montney play include changes in thickness, depth of burial, mass balance calculations, timing and magnitudes of paleotemperature exposure, as well as kerogen concentration and types to determine the distribution of hydrocarbon composition, H2S concentrations and CO2 concentrations. Results show that there is first-, second- and third- order variations in the maturation patterns that impact the hydrocarbon composition. Isomer ratio calculations for butane and propane, in combination with excess methane estimation from produced fluids, are powerful tools to highlight effects of migration in the hydrocarbon distribution. The present-day distribution of hydrocarbons is a result of fluid mixing between hydrocarbons generated in-situ with shorter-chained hydrocarbons (i.e., methane) migrated from deeper, more mature areas proximal to the deformation front, along structural elements like the Fort St. John Graben, as well as through areas of lithology with higher permeability. The BC Montney play appears to have hydrocarbon composition that reflects a larger contribution from in-situ generation, while the Montney play in Alberta has a higher proportion of its hydrocarbon volumes from migrated hydrocarbons. Hydrogen sulphide is observed to be laterally discontinuous and found in discrete zones or pockets. The locations of higher concentrations of hydrogen sulphide do not align with the sulphate-rich facies of the Charlie Lake Formation but can be seen to underlie areas of higher sulphate ion concentrations in the formation water. There is some alignment between CO2 and H2S, particularly south of Dawson Creek; however, the cross-plot of CO2 and H2S illustrates some deviation away from any correlation and there must be other processes at play (i.e., decomposition of kerogen or carbonate dissolution). The sources of sulphur in the produced H2S were investigated through isotopic analyses coupled with scanning electron microscopy, energy dispersive spectroscopy, and mineralogy by X-ray diffraction. The Montney Formation in BC can contain small discrete amounts of sulphur in the form of anhydrite as shown by XRD and SEM-EDX results. Sulphur isotopic analyses indicate that the most likely source of sulphur is from Triassic rocks, in particular, the Charlie Lake Formation, due to its close proximity, its high concentration of anhydrite (18-42%), and the evidence that dissolved sulphate ions migrated within the groundwater in fractures and transported anhydrite into the Halfway Formation and into the Montney Formation. The isotopic signature shows the sulphur isotopic ratio of the anhydrite in the Montney Formation is in the same range as the sulphur within the H2S gas and is a lighter ratio than what is found in Devonian anhydrite and H2S gas. This integrated study contributes to a better understanding of the hydrocarbon system for enhancing the efficiency of and optimizing the planning of drilling and production operations. Operators in BC should include mapping of the Charlie Lake evaporites and structural elements, three-dimensional seismic and sulphate ion concentrations in the connate water, when planning wells, in order to reduce the risk of encountering unexpected souring.
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