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Journal articles on the topic 'Basin (Geology)'

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Published: 4 June 2021

Last updated: 1 February 2022

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1

Pronina, Natalia V., Elena Yu Makarova, Aleksandr Kh Bogomolov, Dmitriy V. Mitronov, and Evgenia V. Kuzevanova. "Geology and coal bearing capacity of the Russian Arctic in connection with prospects of development of the region." Georesursy 21, no. 2 (2019): 42–52. http://dx.doi.org/10.18599/grs.2019.2.42-52.

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Detailed geologic information can be priceless for oil- and gas- oriented geologic exploration in Arctic aquatic basins. Exploration reports on coal basins and deposits located along the Arctic coast are highly detailed and can be used for reconstruction of facies and thermobaric conditions of the poorly explored offshore areas. The article summarizes information on the Russian Arctic coal basins geology: geological structure, tectonic settings, coalforming environments and coal quality parameters. Coal basins of the region contain not only brown and bituminous coals for energetics, but include valuable coking coal (Pechorskiy, Tungusskiy, Beringovskiy basins), anthracite, thermoanthracite and graphite (Taimyrskiy, Tungusskiy basins, Dolgozhdannoye deposit), related coal methane (Pechorskiy basin, coal deposits of Spitzbergen) and trace elements (Lenskiy basin, coal basins and deposits of Chukotka and Frantz Josef Land). It is also can be used for production of advanced materials (adsorbents, sunthetic graphites, etc).

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2

McConachie, B. A., M. G. Barlow, J. N. Dunster, R. A. Meaney, and A. O. Schaap. "THE MOUNT ISA BASIN—DEFINITION, STRUCTURE AND PETROLEUM GEOLOGY." APPEA Journal 33, no. 1 (1993): 237. http://dx.doi.org/10.1071/aj92018.

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The Mount Isa Basin is a new concept to describe the area of Palaeo- to Mesoproterozoic rocks south of the Murphy Inlier (not the Murphy Tectonic Ridge) and inappropriately described as the Mount Isa Inlier. The new basin concept presented in this paper allows the characterisation of basin-wide structural deformation and the recognition of areas with petroleum exploration potential.The northern depositional margin of the Mount Isa Basin is the metamorphic, intrusive and volcanic complex referred to as the Murphy Inlier. The eastern, southern and western boundaries of the basin are obscured by younger basins (Carpentaria, Eromanga and Georgina Basins). The Murphy Inlier rocks comprise the seismic basement to the Mount Isa Basin sequence. Evidence for the continuity of the Mount Isa Basin with the McArthur Basin to the northwest and the Willyama Block (Basin) at Broken Hill to the south is presented. These areas combined with several other areas of similar age are believed to have comprised the Carpentarian Superbasin.The application of seismic exploration within Authority to Prospect (ATP) 423P at the northern margin of the basin was critical to the recognition and definition of the Mount Isa Basin. The northern Mount Isa Basin is structurally analogous to the Palaeozoic Arkoma Basin of Oklahoma and Arkansas in the southern USA but as with all basins it contains unique characteristics, a function of its individual development history. The northern Mount Isa Basin is defined as the basin area northwest of the Mount Gordon Fault.

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3

Tschirhart, Victoria, and Sally J. Pehrsson. "New insights from geophysical data on the regional structure and geometry of the southwest Thelon Basin and its basement, Northwest Territories, Canada." GEOPHYSICS 81, no. 5 (2016): B167—B178. http://dx.doi.org/10.1190/geo2015-0586.1.

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Detailed analysis of gravity and aeromagnetic data covering the southwest Thelon Basin, Northwest Territories, Canada, has provided insight into basement geology that has significance to exploration for uranium and possibly other economic metals in a remote frontier region. Interpretation of basement geology has been constrained by the calibration of gravity and magnetic signatures with Precambrian geology adjacent to the basin and sparse seismic data within the basin, creating the first basement geologic map of the southwest Thelon Basin. The basement to the overlying sedimentary units is dominated by magnetic felsic and mafic bodies variably overlying and intruding the gneissic crystalline basement. Supracrustal belts located outside the basin margins are interpreted to continue below the basin fill. Major structures have been delineated geophysically including the Howard Lake Shear Zone and the Bathurst and McDonald fault systems. Northwest-trending structures forming part of the Bathurst fault system appear to control the unconformity surface morphology and the location of basin depocenters. The geologic interpretations are corroborated by joint gravity and magnetic modeling of profiles that reveal the deepest part of the Thelon Basin reaches depths of [Formula: see text] in an area of subdued magnetic and gravimetric response to the north. The basin is a focus of active exploration for uranium, and we have found that areas along the south and eastern margins underlain by U-rich granitoid rocks may have significant potential where intersected by reactivated faults.

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Wang, Bing, Harry Doust, and Jingyan Liu. "Geology and Petroleum Systems of the East China Sea Basin." Energies 12, no. 21 (2019): 4088. http://dx.doi.org/10.3390/en12214088.

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The back-arc East China Sea Basin lies on extended continental crust at the leading edge of the Eurasian plate. In this study, the basins are described and subdivided according to their tectono-stratigraphic evolution. In order to distinguish between different phases of deformation in basin development, standard basin evolution patterns related to geodynamic drivers are identified as a first step. On the basis of this, standard patterns are recognized in the sedimentary sequences that characterize the area and its tectonic evolution, and linking them to the petroleum systems present is attempted. This is achieved by characterizing and grouping them into basin cycle-related petroleum system types (PSTs). Finally, the development of plays is examined within the petroleum systems in the context of their tectono-stratigraphic evolution, and groups of sub-basins with similar geological history and, therefore, potentially similar petroleum prospectivity are identified. In the East China Sea Basin, four proven and potential PSTs were recognized: (1) Late Cretaceous to Paleocene oil/gas-prone early syn-rift lacustrine–deltaic PST; (2) Eocene gas/oil prone late syn-rift marine PST; (3) Oligocene to Middle Miocene gas/oil-prone early post-rift fluvial–deltaic PST; (4) gas-prone syn-rift turbiditic PST. The geology and petroleum systems of three major sub-basins of the East China Sea Basin, the Xihu Sub-basin, the Lishui Sub-basin, and Okinawa Trough, are discussed in detail, and their petroleum systems and play development are analyzed. Finally, the sub-basins are grouped into “basin families” distinguished by their tectono-stratigraphic development, namely, Northwest to Northeast Shelf Basin (NWSB–NESB), Southwest to Southeast Shelf Basin (SWSB–SESB), and Okinawa Trough basin families, respectively.

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5

Lu, Xushan, Colin Farquharson, Jean-Marc Miehé, Grant Harrison, and Patrick Ledru. "Computer modeling of electromagnetic data for mineral exploration: Application to uranium exploration in the Athabasca Basin." Leading Edge 40, no. 2 (2021): 139a1–139a10. http://dx.doi.org/10.1190/tle40020139a1.1.

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Electromagnetic (EM) methods are important geophysical tools for mineral exploration. Forward and inverse computer modeling are commonly used to interpret EM data. Real-life geology can be complex, and our computer modeling tools need to faithfully represent subsurface features to achieve accurate data interpretation. Traditional rectilinear meshes are less flexible and have difficulty conforming to the complex geometries of realistic geologic models, resulting in large numbers of mesh cells. In contrast, unstructured grids can represent complex geologic structures efficiently and accurately. However, building realistic geologic models and discretizing these models with unstructured grids suitable for EM modeling can be difficult and requires significant effort and specialized computer software tools. Therefore, it is important to develop workflows that can be used to facilitate model building and mesh generation. We have developed a procedure that can be used to build arbitrarily complex geologic models with topography using unstructured grids and a finite-volume time-domain code to calculate EM responses. We present an example of a trial-and-error modeling approach applied to a real data set collected at a uranium exploration project in the Athabasca Basin in Canada. The uranium mineralization is closely related to graphitic fault conductors in the basement. The deep burial depth and small thickness of the graphitic fault conductors demand accurate data interpretation results to guide subsequent drill testing. Our trial-and-error modeling approach builds initial realistic geologic models based on known geology and downhole data and creates initial geoelectrical models based on physical property measurements. Then, the initial model is iteratively refined based on the match between modeled and real data. We show that the modeling method can obtain 3D geoelectrical models that conform to known geology while achieving a good match between modeled and real data. The method can also provide guidance of where future drill holes should be directed.

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6

BOGDANOV, Nikita A. "GEOLOGY OF THE KOMANDORSKY DEEP BASIN." Journal of Physics of the Earth 36, Proceeding1 (1988): S65—S71. http://dx.doi.org/10.4294/jpe1952.36.proceeding1_s65.

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7

BIEN, M. N. "Geology of the Yuanmo Basin, Yunnan*." Bulletin of the Geological Society of China 20, no. 1 (2009): 23–32. http://dx.doi.org/10.1111/j.1755-6724.1940.mp20001003.x.

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8

Caplan, Charlotte A., Helen C. Gildersleeves, Al G. Harding, et al. "Geology of the Northwestern Krania Basin." Bulletin of the Geological Society of Greece 54, no. 1 (2019): 113. http://dx.doi.org/10.12681/bgsg.19375.

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We present a new map of 30 km2 of the northwestern Krania Basin at 1:10,000 scale, including rocks of the Pindos Ophiolite Group and associated units, and the sedimentary fill of the Krania Basin. The Krania Basin is a flexural basin developed in the Middle – Late Eocene and filled first with alluvial fan conglomerates and later with turbidite sandstones and siltstones, following a deepening of the basin. Analysis of the clasts within the sediment, combined with paleoflow analyses, suggest sediment input from the eroding Pindos Ophiolite to the west. The Pindos Ophiolite Group is represented in the area by pillow lavas, sheeted dykes and serpentinized harzburgites of the Aspropotamos Complex. The ophiolite forms imbricated, thrust bounded blocks which show two phases of thrusting, corresponding to Late Jurassic and Eocene stages of ophiolite emplacement. We identify five stages of deformation within the basin itself, starting with Early - Middle Eocene syndepositional extensional faulting associated with the formation of the basin. This was followed by four stages of post-depositional deformation, starting with Late Eocene compression associated with basin closure, which caused thrust faulting and folding of the sediments. Oligocene dextral faulting with a thrust component affected the basin margins. Finally, two normal faulting events with different orientations have affected the basin since the Miocene.

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9

Richards, P. C., and N. G. T. Fannin. "GEOLOGY OF THE NORTH FALKLAND BASIN." Journal of Petroleum Geology 20, no. 2 (1997): 165–83. http://dx.doi.org/10.1111/j.1747-5457.1997.tb00771.x.

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10

Lirong, Dou, Cheng Dingsheng, Li Zhi, Zhang Zhiwei, and Wang Jingchun. "PETROLEUM GEOLOGY OF THE FULA SUB-BASIN, MUGLAD BASIN, SUDAN." Journal of Petroleum Geology 36, no. 1 (2012): 43–59. http://dx.doi.org/10.1111/jpg.12541.

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11

Roberts, D. G. "Basins on the Atlantic seaboard: Petroleum geology, sedimentology and basin evolution." Marine and Petroleum Geology 10, no. 4 (1993): 403–4. http://dx.doi.org/10.1016/0264-8172(93)90085-7.

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12

Eisma, D. "Basins on the Atlantic Seaboard: Petroleum Geology, Sedimentology and Basin Evolution." Sedimentary Geology 87, no. 3-4 (1993): 245–47. http://dx.doi.org/10.1016/0037-0738(93)90008-s.

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13

Liu, Wei Fu, Shuang Long Liu, and Hong Ying Han. "Depositional Model and Development Significance of Clastic Reservoir." Applied Mechanics and Materials 522-524 (February 2014): 1245–48. http://dx.doi.org/10.4028/www.scientific.net/amm.522-524.1245.

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A general geologic sedimentation model for reservoir is made by carefully analyzing the inberent essence of depositional environmentand for clastic rocks of lake basin. The basic model in the streaming environment is composed of two basic facies units: one is the waterway facie and the other is non-waterway facie. The principal characteristics of developing geology and sedimentology have been outlined. It can be commonly used in developing under-producted reserves and raising recovery ratio in the highly developed oil fields.

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14

Cook, R. A., E. M. Crouch, J. I. Raine, C. P. Strong, C. I. Uruski, and G. J. Wilson. "INITIAL REVIEW OF THE BIOSTRATIGRAPHY AND PETROLEUM SYSTEMS AROUND THE TASMAN SEA HYDROCARBON-PRODUCING BASINS." APPEA Journal 46, no. 1 (2006): 201. http://dx.doi.org/10.1071/aj05012.

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Understanding the genesis and habitat of hydrocarbons in a sedimentary basin takes knowledge of that basin at many levels, from basic infill geology to petroleum systems, plays, prospects and detailed sequence stratigraphy. While geophysics can define the basins and their internal structures, biostratigraphy and paleogeography provide greater understanding of basin geology. Micropaleontology and palynology are the chief tools that we need to define both the environment and dimension of time.As an example, the reconstruction of the Tasman Sea region to the mid-Cretaceous (ca 120 Ma) shows that the hydrocarbon-producing Gippsland and Taranaki petroleum basins developed at similar latitudes and in similar geological contexts. Other basins within the region have been lightly explored and need evaluation as to the value of further exploration.As paleontology has developed separately in Australia and New Zealand, comparison of biostratigraphic zones and their chronostratigraphy is critical to understand the similarity or otherwise of the sedimentary record of the two regions. Recent refinement of the NZ timescale and comparative studies on Gippsland Basin wells by NZ paleontologists have provided some key insights that enable us to compare the geological history of both regions more closely, and to recognise similarities in petroleum systems that may enhance petroleum prospects on both sides of the Tasman Sea.

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15

Schintgen, Tom, and Andrea Förster. "Geology and basin structure of the Trier-Luxembourg Basin ? implications for the existence of a buried Rotliegend graben." Zeitschrift der Deutschen Gesellschaft für Geowissenschaften 164, no. 4 (2013): 615–37. http://dx.doi.org/10.1127/1860-1804/2013/0025.

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16

Tamrakar, Naresh Kazi, and Binod Karki. "Geomorphometric properties and variability of sediment delivery ratio and specific sediment yield among sub-basins of the Karra River, Hetauda, central Nepal Sub-Himalaya." Journal of Nepal Geological Society 59 (July 24, 2019): 19–37. http://dx.doi.org/10.3126/jngs.v59i0.24983.

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Geomorphometric properties of watershed-scale are often calculated to characterize drainage basins morphology for evaluating their geomorphic status of basin development. More recently these properties have widely been applied in inferring the sediment delivery ratio and sediment yields of the basin to estimate and know sediment erosion status of drainage basin with the help of morph metric data. In fact, sediment delivery ratio (SDR) and specific sediment yield (SSY) of the basins depend not only on watershed properties but also indirectly on other factors such as climate, hydrology, land use and geology, which can be of low variation for a small watershed. The aims of the present study were to compute some of the geomorphometric parameters of the Karra River Basin (KRB), located in Hetauda, Makawanpur District, Central Nepal, to compare some of these among the sub-basins with varying geology, touse some of parameters in estimating sub-basin-wide SDR and SSY using empirical equations and to infer geomorphic development and erosion status of the basin. Based on hypsometric analysis, the southern sub-basins with mainly gravelly terrain are mostly of mature to unstable phase, whereas the northern sub-basins with bedrocks of the Lower and the Middle Siwalik Subgroups are of Monadnock phase to mature stage of basin development. Sediment delivery ratio (SDR) and specific sediment yield (SSY) estimated for the southern sub-basins of the KRB are relatively lower compared to those estimated for the northern sub-basins. Considering the geology of the KRB and hypsometric integral, although the SDR and SSY of the southern sub-basins are lower compared to the northern sub-basins, the southern sub-basins are vulnerable to erosion because of their unstable geomorphic development stage and pervasive distribution of unconsolidated weak sediments having high erodibility.

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17

KOMATSUBARA, Taku, Geo-Database Information Committee,, Jun TSUKAHARA, et al. "Shallow Subsurface Geology of the Ohmi Basin." Chigaku Zasshi (Jounal of Geography) 119, no. 4 (2010): 683–708. http://dx.doi.org/10.5026/jgeography.119.683.

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18

Rieke, Herman H. "Petroleum Geology of the South Caspian Basin." Journal of Petroleum Science and Engineering 34, no. 1-4 (2002): 137. http://dx.doi.org/10.1016/s0920-4105(01)00167-x.

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19

Albert-Villanueva, E., L. González, T. Bover-Arnal, et al. "Geology of the Falcón Basin (NW Venezuela)." Journal of Maps 13, no. 2 (2017): 491–501. http://dx.doi.org/10.1080/17445647.2017.1333969.

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Legeay, Etienne, Alexandre Pichat, Charlie Kergaravat, et al. "Geology of the Central Sivas Basin (Turkey)." Journal of Maps 15, no. 2 (2018): 406–17. http://dx.doi.org/10.1080/17445647.2018.1514539.

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21

SLOSS, L. L. "Sedimentary Geology: New Perspectives in Basin Analysis." Science 241, no. 4874 (1988): 1839–40. http://dx.doi.org/10.1126/science.241.4874.1839-a.

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22

Su, G., Z. Li, H. Li, et al. "Superimposed Pattern of the Southern Sichuan Basin Revealed by Seismic Reflection Profiles Across Lushan–Chishui, China." Russian Geology and Geophysics 62, no. 6 (2021): 685–700. http://dx.doi.org/10.2113/rgg20194053.

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Abstract The Sichuan Basin is a typical intracraton superimposed basin. It is rich in oil and gas resources in the different sets of sedimentary sequences. It underwent multistage tectonic evolution, which resulted in different types of prototype basins. However, there are still many different opinions on the types and superimposed patterns of the Sichuan Basin in different geologic periods, which largely affect the understanding of the mechanism of effective oil and gas accumulation and preservation. This paper aims to re-recognize several prototype types of the Sichuan Basin by discussing the prototype basins and their superimposed models to deepen the significance of superimposed basin evolution for hydrocarbon accumulation. The regional geological and drilling data are used for a detailed interpretation of seismic reflection profiles across Lushan–Chishui. Then, five regional unconformities are identified with the equilibrium profiles technique which is used to flatten the formation interface in different geologic periods. Based on the unconformities, the southern Sichuan Basin is divided into six tectonic layers, each of which is regarded as a prototype basin: a pre-Sinian crystalline basement (AnZ), a marine rift cratonic basin (Z–S), a marine intracratonic sag basin (P2l–T2l), a marine–continental downfaulted basin (T3x1–T3x3), a continental depressed basin (T3x4–J), and a foreland basin (K–Q). The different prototype basins are vertically superimposed to form a “layered block” geologic structure of the multicycle basins. Affected by the late-stage tectonic transformation, the geologic structure of vertical stratification underwent a strong transformation, which had a profound impact on oil and gas accumulation with the characteristics of early accumulation and late adjustment.

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23

O’Connor, Jim E., Joseph F. Mangano, Daniel R. Wise, and Joshua R. Roering. "Eroding Cascadia—Sediment and solute transport and landscape denudation in western Oregon and northwestern California." GSA Bulletin 133, no. 9-10 (2021): 1851–74. http://dx.doi.org/10.1130/b35710.1.

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Abstract Riverine measurements of sediment and solute transport give empirical basin-scale estimates of bed-load, suspended-sediment, and silicate-solute fluxes for 100,000 km2 of northwestern California and western Oregon. This spatially explicit sediment budget shows the multifaceted control of geology and physiography on the rates and processes of fluvial denudation. Bed-load transport is greatest for steep basins, particularly in areas underlain by the accreted Klamath terrane. Bed-load flux commonly decreases downstream as clasts convert to suspended load by breakage and attrition, particularly for softer rock types. Suspended load correlates strongly with lithology, basin slope, precipitation, and wildfire disturbance. It is highest in steep regions of soft rocks, and our estimates suggest that much of the suspended load is derived from bed-load comminution. Dissolution, measured by basin-scale silicate-solute yield, constitutes a third of regional landscape denudation. Solute yield correlates with precipitation and is proportionally greatest in low-gradient and wet basins and for high parts of the Cascade Range, where undissected Quaternary volcanic rocks soak in 2–3 m of annual precipitation. Combined, these estimates provide basin-scale erosion rates ranging from ∼50 t · km−2 · yr−1 (approximately equivalent to 0.02 mm · yr−1) for low-gradient basins such as the Willamette River to ~500 t · km−2 · yr−1 (∼0.2 mm · yr−1) for steep coastal drainages. The denudation rates determined here from modern measurements are less than those estimated by longer-term geologic assessments, suggesting episodic disturbances such as fire, flood, seismic shaking, and climate change significantly add to long-term landscape denudation.

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24

Carneiro, Celso Dal Ré, Kauan Martins dos Santos, Thiago Rivaben Lopes, Filipe Constantino dos Santos, Jorge Vicente Lopes da Silva, and Ana Lucia Nogueira de Camargo Harris. "Three-dimensional physical models of sedimentary basins as a resource for teaching-learning of geology." Terrae Didatica 14, no. 4 (2018): 379–84. http://dx.doi.org/10.20396/td.v14i4.8654098.

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Three-dimensional modeling connects several fields of knowledge, both basic and applied. 3D models are relevant in educa-tional research because the manipulation of 3D objects favors students' acquisition of spatial vision, but in the Geosciences, there are few didactic publications in Portuguese on the subject. The authors develop an educational research project to produce three-dimensional models of didactic examples of sedimentary basins: the Paraná Basin (Silurian-Upper Cretaceous), the Tau-baté and the São Paulo basins (Neogene). 3D-compatible files will be produced to compose didactic and display material, from maps and geological-structural profiles of certain regional stratigraphic levels of each basin. The research challenges are: (a) to obtain an overview of the available resources for 3D modeling; (b) to evaluate their potential, characteristics, advantages and limitations for applications in Geology and Geosciences; (c) to create computational models of the basins; (d) to produce at least one physical model based on one of the computational models of each basin. The resources will subsidize training work-shops for in-service teachers, technical-scientific articles and Internet pages.

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25

Dickinson, W. R. "Basin geodynamics." Basin Research 5, no. 4 (1993): 195–96. http://dx.doi.org/10.1111/j.1365-2117.1993.tb00066.x.

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Lawrence, S. R., and C. Cornford. "Basin geofluids." Basin Research 7, no. 1 (1995): 1–7. http://dx.doi.org/10.1111/j.1365-2117.1995.tb00090.x.

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Panien, Marion, Guido Schreurs, and Adrian Pfiffner. "Sandbox experiments on basin inversion: testing the influence of basin orientation and basin fill." Journal of Structural Geology 27, no. 3 (2005): 433–45. http://dx.doi.org/10.1016/j.jsg.2004.11.001.

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Postma, George. "The geology of fluvial deposits, sedimentary facies, basin analysis and petroleum geology." Sedimentary Geology 110, no. 1-2 (1997): 149–50. http://dx.doi.org/10.1016/s0037-0738(96)00081-4.

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Fyfe, Laura-Jane C., Nick Schofield, Simon Holford, et al. "Geology and petroleum prospectivity of the Sea of Hebrides Basin and Minch Basin, offshore NW Scotland." Petroleum Geoscience 27, no. 4 (2021): petgeo2021–003. http://dx.doi.org/10.1144/petgeo2021-003.

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The Sea of Hebrides Basin and Minch Basin are late Paleozoic–Mesozoic rift basins located to the NW of the Scottish mainland. The basins were the target of small-scale petroleum exploration from the late 1960s to the early 1990s, with a total of three wells drilled within the two basins between 1989 and 1991. Although no commercially viable petroleum discoveries were made, numerous petroleum shows were identified within both basins, including a gas show within the Upper Glen 1 well in Lower Jurassic limestones. Organic-rich shales have been identified throughout the Jurassic succession within the Sea of Hebrides Basin, with one Middle Jurassic (Bajocian–Bathonian) shale exhibiting a total organic carbon content of up to 15 wt%. The focus of this study is to review the historical petroleum exploration within these basins, and to evaluate whether the conclusions drawn in the early 1990s of a lack of prospectivity remains the case. This was undertaken by analysis of seismic reflection data, gravity and aeromagnetic data, and sedimentological data from both onshore and offshore wells, boreholes and previously published studies. The key findings from our study suggest that there is a low probability of commercially sized petroleum accumulations within either the Sea of Hebrides Basin or the Minch Basin. Ineffective source rocks, likely to be due to low maturities (due to lack of burial) and the fact that the encountered Jurassic and Permian–Triassic reservoirs are of poor quality (low porosity and permeability), has led to our interpretation of future exploration being high risk, with any potential accumulations being small in size. While petroleum accumulations are unlikely within the basin, applying the knowledge obtained from this study could provide additional datasets and insight into petroleum exploration within other NE Atlantic margin basins, such as the Rockall Trough and the Faroe–Shetland Basin.

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Whalen, Michael T. "Barred basins: A model for eastern ocean basin carbonate platforms." Geology 23, no. 7 (1995): 625. http://dx.doi.org/10.1130/0091-7613(1995)023<0625:bbamfe>2.3.co;2.

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31

John-Joe, Traynor. "Arenig sedimentation and basin tectonics in the Harlech Dome area (Dolgellau Basin), North Wales." Geological Magazine 127, no. 1 (1990): 13–30. http://dx.doi.org/10.1017/s0016756800014138.

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AbstractArenig (Ordovician) clastic sediments crop out in the Harlech Dome region (North Wales), and are placed in a single stratigraphic unit: the Allt Lwyd Formation. This unit records a marine transgression onto an erosion surface produced during late Tremadoc arc volcanicity. Four discrete petrofacies are denned, and reflect differing proportions of detritus derived from Tremadoc-type basic-intermediate igneous rocks, and the local sedimentary basement. Initial shallow marine siliciclastic sandstones and conglomerates are overlain by extensive deep water mud-rich units. These generally shallow up into a complex arc-apron deposit, with sediments derived from the eroding Tremadoc arc, as well as from similar, synchronous volcanics. Predominantly epiclastic sandstones and conglomerates were deposited in deltaic and tidal environments in an arc-apron complex, and capped by condensed mudstones and an ironstone, deposited as sea level rose across these systems. Sediments were ponded in north–south orientated troughs and derived from uplifted blocks. Facies and petrofacies distribution were controlled by syn-sedimentary north-south and northeast–southwest faults. The Allt Lwyd Formation was ponded in a fault-controlled basin (the Dolgellau Basin), one of a series of interconnected sub-basins flooded by the Arenig transgression. The sediments preserved reflect deposition during the transgression of a volcanic arc, prior to the extrusion of marginal basin-type volcanics.

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González-Casado, José M., Jorge L. Giner Robles, and Jerónimo López-Martínez. "Bransfield Basin, Antarctic Peninsula: Not a normal backarc basin." Geology 28, no. 11 (2000): 1043. http://dx.doi.org/10.1130/0091-7613(2000)28<1043:bbapna>2.0.co;2.

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Clyde, W. C., W. Hamzi, J. A. Finarelli, S. L. Wing, D. Schankler, and A. Chew. "Basin-wide magnetostratigraphic framework for the Bighorn Basin, Wyoming." Geological Society of America Bulletin 119, no. 7-8 (2007): 848–59. http://dx.doi.org/10.1130/b26104.1.

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34

Liu, J., I. Lerche, K. K. Bissada, and J. Lacey. "The Georges Bank Basin: a quantitative basin analysis study." Terra Nova 3, no. 1 (1991): 70–83. http://dx.doi.org/10.1111/j.1365-3121.1991.tb00846.x.

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35

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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36

Tongkul, F., and F. K. Chang. "Structural geology of the Neogene Maliau Basin, Sabah." Bulletin of the Geological Society of Malaysia 47 (December 1, 2003): 51–61. http://dx.doi.org/10.7186/bgsm47200304.

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37

Yoshino, Hiroatsu, Tetsuo Tanaka, and Hitoshi Yamaguchi. "Petroleum geology in Bintuni Basin in East Indonesia." Journal of the Japanese Association for Petroleum Technology 68, no. 2-3 (2003): 200–210. http://dx.doi.org/10.3720/japt.68.2-3_200.

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38

Weidenfeller, Michael. "Geology of the Neuwied Basin and its borderlands." Jahresberichte und Mitteilungen des Oberrheinischen Geologischen Vereins 101 (April 11, 2019): 61–94. http://dx.doi.org/10.1127/jmogv/101/0003.

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39

Tjia, H. D., Ibrahim Komoo, P. S. Lim, and Tungah Surat. "The Maliau Basin, Sabah: Geology and tectonic setting." Bulletin of the Geological Society of Malaysia 27 (November 30, 1990): 261–92. http://dx.doi.org/10.7186/bgsm27199013.

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40

Nguyen, Trong Tin, and Dinh Ty Nguyen. "Petroleum geology of the Nam Con Son Basin." Bulletin of the Geological Society of Malaysia 37 (July 30, 1995): 1–11. http://dx.doi.org/10.7186/bgsm37199501.

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41

Phillips, Emrys, David M. Hodgson, and Andy R. Emery. "The Quaternary geology of the North Sea basin." Journal of Quaternary Science 32, no. 2 (2017): 117–26. http://dx.doi.org/10.1002/jqs.2932.

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42

Hogg, S. L. "GEOLOGY AND HYDROCARBON POTENTIAL OF THE NEUQUEN BASIN." Journal of Petroleum Geology 16, no. 4 (1993): 383–96. http://dx.doi.org/10.1111/j.1747-5457.1993.tb00349.x.

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43

Sembroni, Andrea, Paola Molin, Francesco Dramis, and Bekele Abebe. "Geology of the Tekeze River basin (Northern Ethiopia)." Journal of Maps 13, no. 2 (2017): 621–31. http://dx.doi.org/10.1080/17445647.2017.1351907.

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Di Pietro, Ilaria, Gian Gabriele Ori, Monica Pondrelli, and Francesco Salese. "Geology of Aeolis Dorsa alluvial sedimentary basin, Mars." Journal of Maps 14, no. 2 (2018): 212–18. http://dx.doi.org/10.1080/17445647.2018.1454350.

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45

Mohriak, W. U., M. R. Mello, J. F. Dewey, and J. R. Maxwell. "Petroleum geology of the Campos Basin, offshore Brazil." Geological Society, London, Special Publications 50, no. 1 (1990): 119–41. http://dx.doi.org/10.1144/gsl.sp.1990.050.01.07.

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Bottrill, T. J. "Geology and Ore Deposits of the Great Basin." Journal of Geochemical Exploration 48, no. 3 (1993): 367–71. http://dx.doi.org/10.1016/0375-6742(93)90013-c.

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Lambert, I. B. "Geology of the Southern McArthur Basin, Northern Territory." Ore Geology Reviews 3, no. 4 (1988): 393–94. http://dx.doi.org/10.1016/0169-1368(88)90030-3.

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48

Grotzinger, J. P. "Geology of the Southern McArthur Basin, Northern Territory." Ore Geology Reviews 3, no. 4 (1988): 401–2. http://dx.doi.org/10.1016/0169-1368(88)90036-4.

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49

Hart, Bruce. "Stratigraphy and hydrocarbon resources of the San Juan Basin: Lessons for other basins, lessons from other basins." Mountain Geologist 58, no. 2 (2021): 43–103. http://dx.doi.org/10.31582/rmag.mg.58.2.43.

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This paper examines the relationships between stratigraphy and hydrocarbon production from the San Juan Basin of New Mexico and Colorado. Abundant data and the long production history allow lessons to be learned, both from an exploration and development perspective, that can be applied in other basins. Conversely, as new play types and technologies are defined and developed elsewhere, the applicability of those tools in the San Juan Basin needs to be understood for well-informed exploration and development activities to continue. The San Juan Basin is a Latest Cretaceous – Tertiary (Paleogene) structure that contains rocks deposited from the Lower Paleozoic to the Tertiary, but only the Upper Cretaceous section has significant hydrocarbon, mostly gas, production. Herein I make the case for studying depositional systems, and the controls thereon (e.g., basin development, eustasy, sediment supply), because they are the first-order controls on whether a sedimentary basin can become a hydrocarbon province, or super basin as the San Juan Basin has recently been defined. Only in the Upper Cretaceous did a suitable combination of forcing mechanisms combine to form source and reservoir rocks, and repeated transgressive-regressive cycles of the Upper Cretaceous stacked multiple successions of source and reservoir rocks in a way that leads to stacked pay potential. Because of the types of depositional systems that could develop, the source rocks were primarily gas prone, like those of other Rocky Mountain basins. Oil-prone source rocks are present but primarily restricted to episodes of peak transgression. A lack of suitable trapping mechanisms helps to explain the relative dearth of conventional oil pools. Although gas production has dropped precipitously in the past decade, driven primarily by overabundance of gas supply associated with the shale-gas boom, the combination of horizontal drilling and multi-stage hydraulic fracturing is being applied to revive oil production from some unconventional stratigraphic targets with success.

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DeCelles, Peter G., and Katherine A. Giles. "Foreland basin systems." Basin Research 8, no. 2 (1996): 105–23. http://dx.doi.org/10.1046/j.1365-2117.1996.01491.x.

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