Relevant bibliographies by topics / Traps (Petroleum geology)

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  1. Journal articles
  2. Dissertations / Theses
  3. Books
  4. Book chapters
  5. Conference papers

Academic literature on the topic 'Traps (Petroleum geology)'

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Published: 4 June 2021
Last updated: 1 August 2024

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Journal articles on the topic "Traps (Petroleum geology)"

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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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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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Sangree, John B. "Stratigraphic traps I: Treatise of petroleum geology, Atlas of oil and gas fields." Marine and Petroleum Geology 9, no. 5 (October 1992): 573. http://dx.doi.org/10.1016/0264-8172(92)90068-p.

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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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Sobolev, P. N., and S. V. Dykhan. "OIL-AND-GAS SOURCE ROCKS AND THE PROBLEM OF PETROLEUM POTENTIAL OF THE ALDAN-MAYA DEPRESSION (SOUTH-EAST OF THE SIBERIAN PLATFORM)." Geology and mineral resources of Siberia, no. 3 (October 2022): 30–38. http://dx.doi.org/10.20403/2078-0575-2022-3-30-38.

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The analysis of existing understandings about distribution of oil-and-gas source rocks was performed for sedimentary section of the Aldan-Maya depression, the large margin structure in the south-east of the Siberian Platform. Taking into account new materials, the oil-and-gas generating potential of these strata was critically examined, and the ideas of previous research period were defined more precisely. On this basis, the sketch map of oil-and-gas bearing stratigraphic breakdown of the Aldan-Maya depression sedimentary cover was compiled. The main elements of hydrocarbon systems, including predicted petroleum plays and petroleum bearing strata were identified, forecast of possible types of traps for various parts of the depression was given. Based on this experience, the contour map of the petroleum potential forecast for the Aldan-Maya depression and adjacent territories was compiled.
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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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Vujovic, Aleksandar, Ritu Gupta, and Gregory C. Smith. "Portfolio analysis of petroleum fields and prospects: a robust statistical method." APPEA Journal 57, no. 2 (2017): 572. http://dx.doi.org/10.1071/aj16095.

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Portfolio analysis of several prospects, fields or assets is an important part of economic analysis routinely done by most exploration, development and production companies, often for large dollar amounts. Yet the methods used have not changed for decades, most are done in complicated and difficult to audit spreadsheets, and commonly they are not statistically robust, meaning they sometimes give incorrect results. The Curtin University Petroleum Geology Group has an active research program working with the Curtin Statistical Group to improve assessment of petroleum volumetrics, risking, scenario and portfolio analysis. This note provides a simple case study of portfolio analysis using an area in the North West Shelf in which we have quickly mapped several leads, prospects and drilled traps. They span a range of risk outcomes from undrilled to drilled, of which some were dry and some were successful to varying degrees. The results allow us to demonstrate how to calculate and aggregate the volumes and dependencies for each structure, correctly add the results using a new statistical methodology and formulate the aggregated volumetric distribution for the portfolio. This workflow can be used for any portfolio in the petroleum and other industries.
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Stoupakova, Antonina V., Nataliya I. Korobova, Alina V. Mordasova, Roman S. Sautkin, Ekaterina D. Sivkova, Maria A. Bolshakova, Mikhail E. Voronin, et al. "Depositional environments as a framework for genetic classification of the basic criteria of petroleum potential." Georesursy 25, no. 2 (June 30, 2023): 75–88. http://dx.doi.org/10.18599/grs.2023.2.6.

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Most classifications of reservoirs, seals and source rocks based on the ability of the rock to generate, accumulate and preserve hydrocarbons, and the genesis of rocks is not always taken into account. The article presents a ranking scheme for continental, coastal-marine and marine sedimentation environments that determine the genesis and properties of the basic criteria of petroleum potential – source rocks, reservoirs, seals and pinch-out traps. Rocks, which can consider as source rock, reservoirs and seals are formed in each depositional environment. However, their structure, mineral composition and distribution area will differ from each other depending on the sedimentary environment and conditions. A combination of elements of the hydrocarbon system formed, corresponding to the sedimentation environment and are characteristic for basins of various types. Continental environments are favorable for the formation of reservoirs and local seals, while the accumulation of source rocks limited by lacustrine, floodplain, and swamp facies. The coastal-marine environment is favorable for the formation of all the basic criteria of petroleum potential, and the transgressive-regressive cyclicity determines the interbedding of source rocks, reservoirs and seals in the section. The marine depositional environments are most favorable for the formation of regional seals and source rocks, including high-carbon formations. The proposed ranking scheme of sedimentary environments and the basic criteria of petroleum potential genetically related to them is applicable in system analysis and selection for analogues of petroleum system elements in sedimentary complexes formed in similar depositional environments.
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Dissertations / Theses on the topic "Traps (Petroleum geology)"

1

Nakanishi, Takeshi. "Practical application of sequence stratigraphy and risk analysis for stratigraphic trap exploration." Title page, contents and abstract only, 2002. http://web4.library.adelaide.edu.au/theses/09PH/09phn1635.pdf.

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"September 2002" Includes bibliographical references (leaves 200-209) Outlines an evaluation procedure for stratigraphic trap exploration by employing sequence stratigraphy, 3D seismic data visualisation and quantitative risk analysis with case studies in an actual exploration basin.
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Lyon, Paul John. "A systematic assessment of fault seal risk to hydrocarbon exploration in the Penola Trough, Otway Basin, South Australia." Thesis, 2008. http://hdl.handle.net/2440/49488.

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A new depth-based method of seismic imaging is used to provide insights into the 3D structural geometry of faults, and to facilitate a detailed structural interpretation of the Penola Trough, Otway Basin, South Australia. The structural interpretation is used to assess fault kinematics through geological time and to evaluate across-fault juxtaposition, shale gouge and fault reactivation potential for three selected traps (Zema, Pyrus and Ladbroke Grove) thus providing a full and systematic assessment of fault seal risk for the area. Paper 1 demonstrates how a depth-conversion method was applied to two-way time seismic data in order to redisplay the seismic in a form more closely representative of true depth, here termed ‘pseudo-depth’. Some apparently listric faults in two-way time are demonstrated to be planar and easily distinguishable from genuine listric faults on pseudo-depth sections. The insights into fault geometry provided by pseudo-depth sections have had a significant impact on the new structural interpretation of the area. Paper 2 presents the new 3D structural interpretation of the area. The geometry of faulting is complex and reflects variable stress regimes throughout structural development and the strong influence of pre-existing basement fabrics. Some basement-rooted faults show evidence of continual reactivation throughout their structural history up to very recent times. Structural analysis of all the live and breached traps of the area demonstrate that traps associated with a basement rooted bounding fault host breached or partially breached accumulations, whereas non-basement rooted faults are associated with live hydrocarbon columns. Papers 3 and 4 demonstrate that for all the traps analysed (Zema, Pyrus and Ladbroke Grove), initial in-place seal integrity was good. The initial seal integrity was provided by a combination of both favourable across fault juxtaposition (Ladbroke Grove) and/or sufficiently well developed shale gouge over potential leaky sand on sand juxtaposition windows to retain significant hydrocarbon columns (Zema, Pyrus). The palaeocolumns observed at Zema and Pyrus indicate that there has been subsequent post-charge breach of seal integrity of these traps while Ladbroke Grove retains a live hydrocarbon column. Evidence of open, permeable fracture networks within the Zema Fault Zone suggest that it is likely to have recently reactivated, thus breaching the original hydrocarbon column. Analysis of the in-situ stress tensor and fault geometry demonstrates that most of the bounding faults to the selected traps are at or near optimal orientations for reactivation in the in-situ stress tensor. The main exception being the Ladbroke Grove Fault which has a NW-SE trending segment (associated with a relatively high risk of fault reactivation and possible leakage at the surface) and an E-W trending segment (associated with a relatively low risk of fault reactivation and a present day live column). The free water level of the Ladbroke Grove accumulation coincides with this change in fault orientation.
Thesis (Ph.D.) - University of Adelaide, Australian School of Petroleum, 2008
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3

Lyon, Paul John. "A systematic assessment of fault seal risk to hydrocarbon exploration in the Penola Trough, Otway Basin, South Australia." 2008. http://hdl.handle.net/2440/49488.

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A new depth-based method of seismic imaging is used to provide insights into the 3D structural geometry of faults, and to facilitate a detailed structural interpretation of the Penola Trough, Otway Basin, South Australia. The structural interpretation is used to assess fault kinematics through geological time and to evaluate across-fault juxtaposition, shale gouge and fault reactivation potential for three selected traps (Zema, Pyrus and Ladbroke Grove) thus providing a full and systematic assessment of fault seal risk for the area. Paper 1 demonstrates how a depth-conversion method was applied to two-way time seismic data in order to redisplay the seismic in a form more closely representative of true depth, here termed ‘pseudo-depth’. Some apparently listric faults in two-way time are demonstrated to be planar and easily distinguishable from genuine listric faults on pseudo-depth sections. The insights into fault geometry provided by pseudo-depth sections have had a significant impact on the new structural interpretation of the area. Paper 2 presents the new 3D structural interpretation of the area. The geometry of faulting is complex and reflects variable stress regimes throughout structural development and the strong influence of pre-existing basement fabrics. Some basement-rooted faults show evidence of continual reactivation throughout their structural history up to very recent times. Structural analysis of all the live and breached traps of the area demonstrate that traps associated with a basement rooted bounding fault host breached or partially breached accumulations, whereas non-basement rooted faults are associated with live hydrocarbon columns. Papers 3 and 4 demonstrate that for all the traps analysed (Zema, Pyrus and Ladbroke Grove), initial in-place seal integrity was good. The initial seal integrity was provided by a combination of both favourable across fault juxtaposition (Ladbroke Grove) and/or sufficiently well developed shale gouge over potential leaky sand on sand juxtaposition windows to retain significant hydrocarbon columns (Zema, Pyrus). The palaeocolumns observed at Zema and Pyrus indicate that there has been subsequent post-charge breach of seal integrity of these traps while Ladbroke Grove retains a live hydrocarbon column. Evidence of open, permeable fracture networks within the Zema Fault Zone suggest that it is likely to have recently reactivated, thus breaching the original hydrocarbon column. Analysis of the in-situ stress tensor and fault geometry demonstrates that most of the bounding faults to the selected traps are at or near optimal orientations for reactivation in the in-situ stress tensor. The main exception being the Ladbroke Grove Fault which has a NW-SE trending segment (associated with a relatively high risk of fault reactivation and possible leakage at the surface) and an E-W trending segment (associated with a relatively low risk of fault reactivation and a present day live column). The free water level of the Ladbroke Grove accumulation coincides with this change in fault orientation.
http://proxy.library.adelaide.edu.au/login?url= http://library.adelaide.edu.au/cgi-bin/Pwebrecon.cgi?BBID=1339545
Thesis (Ph.D.) - University of Adelaide, Australian School of Petroleum, 2008
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Nakanishi, Takeshi. "Practical application of sequence stratigraphy and risk analysis for stratigraphic trap exploration / Takeshi Nakanishi." Thesis, 2002. http://hdl.handle.net/2440/21828.

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"September 2002"
Includes bibliographical references (leaves 200-209)
xi, 209, [51] leaves : ill. (chiefly col.), maps, plates (chiefly col.) ; 30 cm.
Outlines an evaluation procedure for stratigraphic trap exploration by employing sequence stratigraphy, 3D seismic data visualisation and quantitative risk analysis with case studies in an actual exploration basin.
Thesis (Ph.D.)--University of Adelaide, National Centre for Petroleum Geology and Geophysics, 2002
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(13114611), Wesley James Foi Nichols. "Surface and borehole geophysical analysis of structures within the Callide Basin, eastern Central Queensland." Thesis, 2001. https://figshare.com/articles/thesis/Surface_and_borehole_geophysical_analysis_of_structures_within_the_Callide_Basin_eastern_Central_Queensland/20334999.

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Traditional geophysical techniques, such as electrical, magnetic, seismic and gamma spectroscopic methods, have been deployed across the Callide Basin, Eastern Central Queensland, intent on delineating basin -wide structures. Further, innovative surface and borehole geophysical techniques have been applied for coal mine -scale exploration and production with the intention of reducing global geological ambiguity and optimising exploration resources at Callide Coalfields.


A very low frequency electromagnetic surface impedance mapping method, the SIROLOG downhole technique, acoustic scanning, electromagnetic tomography and

full wave -form sonic borehole logging have been trialed for geological hazard and mine design applications at Callide Coalfields as the precursor to their wider

application and acceptance in the Australian coal industry.


In this thesis, the theoretical basis for these techniques is provided. However, more importantly, the case studies presented demonstrate the role that these geophysical

techniques have played in identifying geological structures critical to mining.

Reverse faults that daylight in highwalls and intrusions constitute geological hazards that affect safety, costs and scheduling in mining operations. Identification of the limit

of oxidation of coal seams (coal subcrop) is critical in mine design. During the course of this thesis, the application of geophysical techniques resulted in:

a) a major structure (the "Trap Gully Monocline") being redefined from its original

interpretation as a normal fault to a monocline that is stress -relieved by minor scale thrust faulting;

b) two previously unidentified intrusions (the Kilburnie "Homestead" plug and The Hut "Crater" plug) that impinge on mining have been discovered;

c) the delineation of two coal subcrop lines has resulted in the discovery of an additional 1.5 million tonnes of coal reserve at Boundary Hill mine and the successful redesign of mining strips at The Hut Central Valley and Eastern

Hillside brownfield sites; and

d) the first ever attempt to petrophysically characterise the lithotypes within the Callide Basin.

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Books on the topic "Traps (Petroleum geology)"

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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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C, Surdam Ronald, ed. Seals, traps, and the petroleum system. Tulsa, Okla: American Association of Petroleum Geologists, 1997.

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1961-, Sorkhabi Rasoul B., Tsuji Yoshihiro, American Association of Petroleum Geologists, and Japan Oil, Gas and Metals National Corporation, eds. Faults, fluid flow, and petroleum traps. Tulsa, Oklahoma: The American Association of Petroleum Geologists, 2005.

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

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Lowrie, Allen. Seismic stratigraphy and hydrocarbon traps: Louisiana onshore and offshore. Tulsa, OK: Society of Exploration Geophysicists, 1994.

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Jenyon, Malcolm K. Oil and gas traps: Aspects oftheir seismostratigraphy, morphology and development. Chichester: Wiley, 1990.

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Jenyon, Malcolm K. Oil and gas traps: Aspects of their seismostratigraphy, morphology, and development. Chichester: Wiley, 1990.

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Konstantinovich, Gavrish Vladimir, and Instytut heolohichnykh nauk (Akademii͡a︡ nauk Ukraïnsʹkoï RSR), eds. Geologii͡a︡ i neftegazonosnostʹ Dneprovsko-Donet͡s︡koĭ vpadiny--glubinnye razlomy i kombinirovannye neftegazonosnye lovushki. Kiev: Nauk. dumka, 1991.

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Book chapters on the topic "Traps (Petroleum geology)"

1

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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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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Shilovskii, Andrei. "Influence of Trap Magmatism on the Oil and Gas Potential of Sedimentary Deposits." In Recent Research on Sedimentology, Stratigraphy, Paleontology, Tectonics, Geochemistry, Volcanology and Petroleum Geology, 259–61. Cham: Springer Nature Switzerland, 2023. http://dx.doi.org/10.1007/978-3-031-43222-4_57.

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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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Selley, Richard C., and Stephen A. Sonnenberg. "Traps and Seals." In Elements of Petroleum Geology, 361–418. Elsevier, 2023. http://dx.doi.org/10.1016/b978-0-12-822316-1.00007-0.

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Kacewicz, Marek. "Mathematics Between Source And Trap: Uncertainty In Hydrocarbon Migration Modeling." In Computers in Geology - 25 Years of Progress. Oxford University Press, 1994. http://dx.doi.org/10.1093/oso/9780195085938.003.0011.

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Petroleum geology provides a wide spectrum of data that differs from frontier to mature areas. Data quality and quantity control which mathematical methods and techniques should be applied. In this paper two mathematical methods are shown: fuzzy-set theory and possibility theory as applied to permeability prediction and stochastic modeling of traps and leaks. Both methods are used in the modeling of hydrocarbon migration efficiency. Examples of how data uncertainty may affect final assessment of oil accumulation are presented. The complexity of petroleum geology and its importance to society stimulate research in different scientific areas including mathematical geology, which is becoming steadily more important. Armed with workstations, mainframes, and supercomputers, research laboratories in the petroleum industry investigate sophisticated mathematical techniques and develop complex mathematical models which can speed and improve exploration and lower total exploration costs. Together with classical analysis of geological, geochemical, and seismic data, mathematics provides an additional tool for basin research. The elements of petroleum systems—maturation, expulsion and primary migration, secondary migration, seals, reservoirs, and traps—may be better described by properly applied mathematical techniques. The complexity of petroleum geology and its importance to society stimulate research in different scientific areas including mathematical geology, which is becoming steadily more important. Armed with workstations, mainframes, and supercomputers, research laboratories in the petroleum industry investigate sophisticated mathematical techniques and develop complex mathematical models which can speed and improve exploration and lower total exploration costs. Together with classical analysis of geological, geochemical, and seismic data, mathematics provides an additional tool for basin research. The elements of petroleum systems—maturation, expulsion and primary migration, secondary migration, seals, reservoirs, and traps—may be better described by properly applied mathematical techniques. The applicability of mathematical methods differs in frontier and mature areas and depends upon the quality and quantity of available information. Frontier areas for which data are mostly qualitative require methods which can handle imprecise and limited information easily. Fuzzy-set theory with fuzzy inference algorithms and artificial intelligence are useful approaches. Cokriging and "soft" geostatistical approaches also may be helpful.
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"Petroleum Reservoirs." In Petroleum Engineering Explained: Basic Concepts for Novices, 49–73. The Royal Society of Chemistry, 2020. http://dx.doi.org/10.1039/9781788016681-00049.

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Petroleum reservoirs are vast stretches of porous rocks in which the interlinked pores are filled with oil, natural gas and water. Oil and natural gas found today were formed hundreds of millions of years ago deep underground. Over millions of years the oil and natural gas have migrated to the surface, with the majority of these resources being lost to the atmosphere. Some of petroleum, however, is caught in geological structures known as traps. This chapter begins by covering some basic geology concepts before looking at the types of geological structures that might allow the accumulation oil and gas. Petroleum reservoirs are characterised by their porosity, permeability and the fluid saturations. We will examine how we may use these factors to estimate the amount of oil and gas that might be found in a reservoir. Finally, we will look at the techniques used by petroleum engineers and geophysicists to locate potential petroleum reservoirs deep underground.
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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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Weimer, Paul, and Renaud Bouroullec. "Petroleum Geology of the Mississippi Canyon, Atwater Valley, Western Desoto Canyon, and Western Lloyd Areas, Northern Deep Gulf of Mexico: Traps, Reservoirs, and Their Timing." In New Understanding of the Petroleum Systems of Continental Margins of the World: 32nd Annual, 110–32. SOCIETY OF ECONOMIC PALEONTOLOGISTS AND MINERALOGISTS, 2012. http://dx.doi.org/10.5724/gcs.12.32.0110.

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Sullivan, Raymond, Doris Sloan, Jeffrey R. Unruh, and David P. Schwartz. "Preface." In Regional Geology of Mount Diablo, California: Its Tectonic Evolution on the North America Plate Boundary. Geological Society of America, 2021. http://dx.doi.org/10.1130/2021.1217(000).

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ABSTRACT This paper does not have an abstract. The Northern California Geological Society held its first meeting in May 1944. Over the years, a monthly lecture series and occasional field trips evolved to serve as the main venues for the Society. At first, meetings of the Society were held in various locations across the San Francisco Bay area, but eventually settled in San Francisco because of its concentration of petroleum and mining companies. One of the first field trips organized by the Society was a two-day trip to Mount Diablo held on 12–13 May 1950. This event marked the beginning of a close connection between the Society and the mountain. The Society prospered over the next few decades, but as the petroleum and mining companies relocated away from San Francisco, the membership broadened and the meeting location was moved to the East Bay and near Mount Diablo. Seventy-five years after its founding, the Society proposed to celebrate this anniversary by assembling a volume of new research and field guides by the members...
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Conference papers on the topic "Traps (Petroleum geology)"

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Bare, V., I. Fili, A. Leka, and A. Mezini. "Using of New Seismic Interpretation for Exploration of Carbonate Traps in External Albanides." 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/10.3997/2214-4609.201406054.

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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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Mitrea, Ioana Cornelia, Florinel Dinu, and Valentin Mihail Batistatu. "HYDROCARBON TRAP TYPES ON THE BLACK SEA OFFSHORE ROMANIA." In 22nd SGEM International Multidisciplinary Scientific GeoConference 2022. STEF92 Technology, 2022. http://dx.doi.org/10.5593/sgem2022/1.1/s01.001.

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The first oil discovery from Romanian Black Sea area was in 1987, relatively late compared with the first successful Romanian onshore well, more than 100 years earlier. Starting from that moment and continuing till recent years, several discoveries were done; some are already put into production and some others are still in the exploration phase. In order to extract as much oil as possible and also to define new hydrocarbon reservoirs, it is mandatory to have a proper understanding of the petroleum systems from the area. A petroleum system is represented by all the elements (source rock, reservoir rock, seal and trap), together with the processes (generation, migration, accumulation and preservation) which together lead to a hydrocarbon accumulation. Because the Black Sea basin has a complex geology, with combined tectonic regime, extensional at the opening of the basin converted to compressional regime in the later stages, and also with different stratigraphic features, the resulted traps are structural, stratigraphic or combined, with different characteristics. The purpose of this article is to analyze the traps which were identified in the Romanian Black Sea area, both in shallow and deep water zones, to classify them and understand how were formed. This aspect has a big impact in the grasp of the reservoir extensions as well as in identifying the best place for drilling of new wells.
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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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Satyana, A. H. "The Neogene in Indonesia: The Most Important Period of Geologic Evolution and Formation of Petroleum Resources." In Indonesian Petroleum Association - 46th Annual Convention & Exhibition 2022. Indonesian Petroleum Association, 2022. http://dx.doi.org/10.29118/ipa22-g-313.

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The Neogene (23 – 2.6 Ma, including Miocene and Pliocene epochs) is a very important period for Indonesian geology. In this period Indonesia got its present configuration and became the main time controlling the geological setting for the occurrences of energy and mineral resources, as well as geologic disasters. There are important differences in the geological evolution of the Neogene between the western and eastern parts of Indonesia. In Western Indonesia, the outline of the evolution is that transgression occurred in all basins with maximum transgression occurred by the end of early Miocene. Then followed by compression and inversion tectonic events as well as regressive sedimentation from the mid-Miocene to the Pliocene in Sumatra, Natuna, Java basins; while deltaic sedimentation characterized the period in eastern Borneo basins. Volcanism became an important element in the Neogene for Sumatra, Java, Lesser Sunda. In Eastern Indonesia, during the Miocene there was drifting of terranes and their syn-drifting sedimentation, then the terranes collided and were fragmented in the Miocene-Pliocene followed by the formation of regional strike-slip faults, subduction rollback, and the opening of the Banda Sea. The period was also characterized by post-collision molassic sedimentation into the foreland basins. These geological events strongly controlled the petroleum system in every basin in Western and Eastern Indonesia. Although some elements of the petroleum system are Paleogene or Pre-Cenozoic in ages, most of the petroleum system processes associated with final trap formation, petroleum generation, migration, accumulation, and preservation of accumulation occurred in the Neogene. The deltaic basins of Kutai and Tarakan in Western Indonesia and the carbonate basins in Eastern Indonesia (Salawati and Banggai) have their proven petroleum system elements and processes within the Neogene period. Thus, studying the geological evolution and its implications for the petroleum system in the Neogene is very important. The knowledge of this can be applied particularly to less explored basins in Indonesia which are geologically analogue to the productive basins.
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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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Saerina, Anisa N., Imam F. Romario, and Hadi Nugroho. "Central Java Hydrocarbon Potential: North Serayu Petroleum System from Source to Trap Based on Geology, Geochemistry, and Geophysics Analysis." In International Petroleum Technology Conference. International Petroleum Technology Conference, 2016. http://dx.doi.org/10.2523/iptc-18654-ms.

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Livsey, A. "Petroleum Systems Analysis of The Tungkal PSC Area, South Sumatra – A Means of Adding New Life to A Mature Area." In Digital Technical Conference. Indonesian Petroleum Association, 2020. http://dx.doi.org/10.29118/ipa20-g-399.

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South Sumatra is considered a mature exploration area, with over 2500MMbbls of oil and 9.5TCF of gas produced. However a recent large gas discovery in the Kali Berau Dalam-2 well in this basin, highlights that significant new reserve additions can still be made in these areas by the re-evaluation of the regional petroleum systems, both by identification of new plays or extension of plays to unexplored areas. In many mature areas the exploration and concession award history often results in successively more focused exploration programmes in smaller areas. This can lead to an increased emphasis on reservoir and trap delineation without further evaluation of the regional petroleum systems and, in particular, the hydrocarbon charge component. The Tungkal PSC area is a good example of an area that has undergone a long exploration history involving numerous operators with successive focus on block scale petroleum geology at the expense of the more regional controls on hydrocarbon prospectivity. An improved understanding of hydrocarbon accumulation in the Tungkal PSC required both using regional petroleum systems analysis and hydrocarbon charge modelling. While the Tungkal PSC operators had acquired high quality seismic data and drilled a number of wells, these were mainly focused on improving production from the existing field (Mengoepeh). More recent exploration-driven work highlighted the need for a new look at the hydrocarbon charge history but it was clear that little work had been done in the past few year to better understand exploration risk. This paper summarises the methodology employed and the results obtained, from a study, carried out in 2014-15, to better understand hydrocarbon accumulation within the current Tungkal PSC area. It has involved integration of available well and seismic data from the current and historical PSC area with published regional paleogeographic models, regional surface geology and structure maps, together with a regional oil generation model. This approach has allowed a better understanding of the genesis of the discovered hydrocarbons and identification of areas for future exploration interest.
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Azman, Mohd Fairuz, Tunku Ahmad Farhan Tunku Kamaruddin, Nis Ilyani Mohmad, Luqman Hakim Zulkafli, Khiril Shahreza Salleh, and Rizal Bakar. "Rejuvenating Waterflood Reservoir in a Complex Geological Setting of a Matured Brown Field." In International Petroleum Technology Conference. IPTC, 2023. http://dx.doi.org/10.2523/iptc-23056-ea.

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Abstract Field A consists of multi stacked reservoirs in high geological complexity and heterogeneity setting, with waterflooding has been the secondary drive mechanism for the past two decades. However, in recent years, the field experiencing significant production decline that warrant immediate mitigation plan and action. Therefore, this paper highlights challenges and best practices in rejuvenating water injected reservoir to improve field production by integrating geological re-interpretation, data acquisition and analytical evaluation. The reservoir is defined in deltaic environment with complex fluvial reservoir architecture. Despite no indication of structural trap or compartmentalization, there is significant variation in reservoir performance across the field indicates lateral heterogeneity that is affecting the areal sweep efficiency. Poor production-injection allocation data due to commingled production, aggravated by tubing leaks have hindered for an optimum formulation of waterflood strategy in the past. As part of the mitigation plan, depo-facies definition and stratigraphy boundaries were further refined, guided by well and reservoir pressure performance. Besides, inter-well tracer injection implementation proved to be the game changer - unfolded hydrodynamic connectivity and flow path of injected water understanding, established actual producer and injector pairing, and identified poor or unswept areas. It was supported by comprehensive analytical water injection performance analysis including Hall's Plot, Chan's Plot, Jordan's Plot as part of the routine surveillance activities to trigger any non-conformance. More aggressive well intervention also helped to identify and rectify well issues. As the outcomes, there is opportunity to increase water injection rate by 30% field wide by reactivating idle wells, converting producers to injector, and maximizing the existing injection within the safe fracture limit. The subsurface risks on fracture gradient uncertainty and sweep inefficiency due to water cycling to be mitigated via injectivity test with gradual injection, close monitoring of liquid rate handling at surface, and pattern balancing between injectors and producers. The liquid rate is expected to be restored and sustained nearing the historical peak, hence improve field production and temper the decline. This paper presents the best practices to address the challenges in a matured waterflood reservoirs, considering the complex geology setting. Understanding of the flood pattern from tracer analysis, supplemented by producer-injection performance assessment and well integrity status validation enabled water injection to be ramped up at the right area in strategically and safely manner.
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Al Abry, M., B. Al Mahrouqi, S. Al Farsi, S. Al Busaidi, Y. Al Hosni, and H. Al Shabibi. "Automation and Standardization to Accelerate Well Delivery and Resource Allocation, in a Complex Field Development." In International Petroleum Technology Conference. IPTC, 2024. http://dx.doi.org/10.2523/iptc-24159-ea.

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Abstract The development of oil fields are becoming more complex and more challenging as the industry moving away from easy oil, the pursuit of efficiency, reliability, and consistency has become paramount. One strategy that organizations often employ to achieve these goals, especially in complex oil fields development, is automation and standardization of repetitive process. Automation refers to the utilization of technology and software systems to perform tasks and processes with minimal human intervention, improving work quality and Standardization, on the other hand, is the process of establishing uniform templates and guidelines, and specifications across the organization. It aims to create a cohesive framework that ensures consistency in product quality, service delivery, and compliance with KPI's. The convergence of automation and standardization in a complex field represents a transformative project that can redefine how organizations operate. Such projects involve the integration of automated features and the establishment of standardized practices to not only enhance efficiency but also improve quality during planning phase but as well as allowing time to dive deep, react and enhance the end results. Well delivery planning and proposals are fundamental steps in the oil and gas industry, serving as a roadmap for drilling pro jects and providing stakeholders with the information they need to make informed decisions regarding investments and resource allocation. These processes require thorough analysis, attention to detail, and adherence to industry best practices and regulations. Fifteen well planning proposals were selected to implement those automated workflows via existing tool and software with standardized outputs which are relevant to production geology input. The targeted reservoir is a Fluvial system with channelized stratigraphic trap, stacked heterogenous reservoirs. The complexity of the field was captured with range of Models and scenarios. Which later used for the planning the field development. The well selection process had to reflect for the high range of uncertainty and complexity of the reservoir. The implementation trail was led to a time saving by 45%, less iterations between contributes and peer assist and improved work quality. this project was implemented during the business cycle of resource allocation in which the benefits and the values were remarkable. The initiative of automation and standardization will be expanded in future to cover all business cycles in field development, modelling, well planning, end of well report, reservoir management activities and reserve classification and reporting.
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