Hydrocarbon systems of the Crimean-Caucasian segment of the Alpine folded system

The article is devoted to the generation and accumulation systems in the territory of the Crimean-Caucasian segment of the Alpine folded system. An area of prolonged and stable sagging in the Mesozoic and Cenozoic – the Azov-Kuban Trough, which is a typical foreland basin – is distinguished within this segment. According to the results of geological and geochemical studies and modelling, depocentres are identified in this area, consolisated in four generative and accumulative hydrocarbon systems: Triassic-Jurassic, Cretaceous, Eocene and Maikop. Chemical-bitumenological, pyrolytic and coal petrology analysis of rock samples were carried out to assess geochemical conditions of oil and gas content in Meso-Cenozoic sediments. The modelling results made it possible to study and model the elements and processes of hydrocarbon systems in the Meso-Cenozoic in the Western Crimean-Caucasian region. It has been established that the extended catagenetic zoning is typical for these areas, which is caused by high rates of sedimentation and sagging, and large thicknesses of oil-bearing sediments in the source of oil formation, accordingly. The degree of organic matter depletion characterized the residual potential of the oil and gas source strata, was investigated. It is important for predicting and assessing the possibility of hydrocarbon generation.

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Formation conditions and evolution of oil and gas source strata of the Laptev sea shelf ore and gas province

Proceedings of higher educational establishments Geology and Exploration ◽

10.32454/0016-7762-2020-63-3-46-59 ◽

2021 ◽

pp. 46-59

Author(s):

V. Yu. Kerimov ◽

Yu. V. Shcherbina ◽

A. A. Ivanov

Keyword(s):

Oil And Gas ◽

Numerical Models ◽

Sedimentary Basins ◽

Water Area ◽

Source Rocks ◽

Gas Content ◽

Laptev Sea ◽

Hydrocarbon Generation ◽

Gas Source ◽

The Laptev Sea

Introduction. To date, no unified well-established concepts have been developed regarding the oil and gas geological zoning of the Laptev Sea shelf, as well as other seas of the Eastern Arctic. Different groups of researchers define this region either as an independently promising oil and gas region [7, 8], or as a potential oil and gas basin [1].Aim. To construct spatio-temporal digital models of sedimentary basins and hydrocarbon systems for the main horizons of oil and gas source rocks. A detailed analysis of information on oil and gas content, the gas chemical study of sediments, the characteristics of the component composition and thermal regime of the Laptev sea shelf water area raises the question on the conditions for the formation and evolution of oil and gas source strata within the studied promising oil and gas province. The conducted research made it possible to study the regional trends in oil and gas content, the features of the sedimentary cover formation and the development of hydrocarbon systems in the area under study.Materials and methods. The materials of production reports obtained for individual large objects in the water area were the source of initial information. The basin analysis was based on a model developed by Equinor specialists (Somme et al., 2018) [14—17], covering the time period from the Triassic to Paleogene inclusive and taking into account the plate-tectonic reconstructions. The resulting model included four main sedimentary complexes: pre-Aptian, Apt-Upper Cretaceous, Paleogene, and Neogene-Quaternary.Results. The calculation of numerical models was carried out in two versions with different types of kerogen from the oil and gas source strata corresponding to humic and sapropel organic matter. The results obtained indicated that the key factor controlling the development of hydrocarbon systems was the sinking rate of the basins and the thickness of formed overburden complexes, as well as the geothermal field of the Laptev Sea.Conclusion. The analysis of the results obtained allowed the most promising research objects to be identified. The main foci of hydrocarbon generation in the Paleogene and Neogene complexes and the areas of the most probable accumulation were determined. Significant hydrocarbon potential is expected in the Paleogene clinoforms of the Eastern Arctic.

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APPLICATION OF ONE-DIMENSIONAL PALEOTEMPERATURE MODELING TO ESTIMATE THE HYDROCARBON POTENTIAL OF CRETACEOUS SEDIMENTS OF THE MIDDLE AMUR SEDIMENTARY BASIN

Tikhookeanskaya Geologiya ◽

10.30911/0207-4028-2021-40-4-87-98 ◽

2021 ◽

Vol 40 (4) ◽

pp. 87-98

Author(s):

P.N. Prokhorova ◽

◽

E.P. Razvozzhaeva ◽

V.I. Isaev ◽

◽

...

Keyword(s):

Oil And Gas ◽

Sedimentary Basin ◽

Gas Content ◽

Hydrocarbon Potential ◽

Hydrocarbon Generation ◽

Gas Generation ◽

One Dimensional ◽

Middle Amur Sedimentary Basin ◽

History Of ◽

History Of Formation

The prospects of oil and gas content of the Cretaceous-Paleogene deposits of the Middle Amur sedimentary basin within the Pereyaslavsky graben are clarified on the basis of updated data on the tectonic-stratigraphic complexes of the basin using the method of one-dimensional paleotemperature modeling. It is established that throughout the history of formation of the studied part of Pereyaslavsky graben hydrocarbon generation could occur in lower Cretaceous sediments of the Assikaevsky and Alchansky/Strelnikovsky suites. The gas generation conditions for the Assykaevsky formation are still maintained.

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HYDROCARBON GENERATION IN THE AMADEUS BASIN, CENTRAL AUSTRALIA

The APPEA Journal ◽

10.1071/aj83003 ◽

1984 ◽

Vol 24 (1) ◽

pp. 42

Author(s):

K. S. Jackson D. M. McKirdy ◽

J. A. Deckelman

Keyword(s):

Oil And Gas ◽

Source Rocks ◽

Hydrocarbon Generation ◽

Liquid Hydrocarbons ◽

Gas Source ◽

Organic Facies ◽

Hydrocarbon Fields ◽

Central Australia ◽

Oil Source ◽

To Receive

The Proterozoic to Devonian Amadeus Basin of central Australia contains two hydrocarbon fields — oil and gas at Mereenie and gas at Palm Valley, both within Ordovician sandstone reservoirs. Significant gas and oil shows have also been recorded from Cambrian sandstones and carbonates in the eastern part of the basin. The hydrocarbon generation histories of documented source rocks, determined by Lopatin modelling, largely explain the distribution of the hydrocarbons. The best oil and gas source rocks occur in the Ordovician Horn Valley Siltstone. Source potential is also developed within the Late Proterozoic sequence, particularly the Gillen Member of the Bitter Springs Formation, and the Cambrian.Consideration of organic maturity, relative timing of hydrocarbon generation and trap formation, and oil/source typing leads to the conclusion that the Horn Valley Siltstone charged the Mereenie structure with gas and oil. At Palm Valley, only gas and minor condensate occur because the trap was formed too late to receive an oil charge. Differences in organic facies may also, in part, account for the dry gas and lack of substantial liquid hydrocarbons at Palm Valley. In the eastern Amadeus Basin, the Ordovician is largely absent but Proterozoic sources are well placed to provide the gas discovered by Ooraminna 1 and Dingo 1. Any oil charge here would have preceded trap development.

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NEW THINKING ON THE PETROLEUM PROSPECTIVITY OF DEEP MESOZOIC SEDIMENTS IN NEW ZEALAND BASINS

The APPEA Journal ◽

10.1071/aj98021 ◽

1999 ◽

Vol 39 (1) ◽

pp. 386 ◽

Cited By ~ 5

Author(s):

R.A. Cook ◽

R.C. Gregg ◽

D.J. Bennett

Keyword(s):

New Zealand ◽

Seismic Data ◽

Oil And Gas ◽

Good Source ◽

Seismic Surveys ◽

South Basin ◽

Sedimentary Sequences ◽

Gas Source ◽

New Thinking ◽

Geochemical Studies

Geochemical studies, reinterpretation of early seismic data and information from new seismic surveys are extending the concept of economic basement for hydrocarbons in several New Zealand basins. Older Cretaceous and even Jurassic and Triassic rocks, previously considered to be 'basement' by petroleum explorationists, may have significance as petroleum prospects.Triassic–Jurassic Murihiku Supergroup sedimentary sequences are up to 15 km thick, and the upper parts are still of low metamorphic rank. Vitrinite reflectances and Hydrogen Indexes from Murihiku Supergroup coals sampled from outcrop and drillholes indicate good oil potential, and, together with rock porosity of up to 18%, suggest that the Murihiku Supergroup may be prospective.In the offshore Canterbury Basin, reinterpretation of seismic data has shown there is probably a thick sedimentary section below what was previously mapped as the regional basement horizon. This seismic interval can be related to a similar section developed in the adjacent Great South Basin where a mid-Cretaceous, rift- fill section of hydrocarbon-bearing rocks, drilled in the Kawau–1 well had good source and reservoir potential.In the onshore Canterbury Basin, a recent vibroseis survey has revealed apparent sedimentary section extending down to more than 4,000 m which might also be the expression of a mid-Cretaceous rift-fill section, similar to that in the nearby Great South Basin and in the formerly adjacent Taranaki Basin, or possibly the older Murihiku Supergroup. This potential for a mature oil and gas source section provides the basis for further exploration of the area.There are similar prospective sequences in several other New Zealand basins.

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Seismogeological characteristics and oil-and-gas prospects of the cambrian sediments within the Vilyui hemisyneclise

Недропользование. Горное дело. Направления и технологии поиска, разведки и разработки месторождений полезных ископаемых. Экономика. Геоэкология: Материалы XVI международной конференции (20-24 апреля 2020, Новосибирск) ◽

10.18303/b978-5-4262-0102-6-2020-007 ◽

2020 ◽

Author(s):

Igor A. Gubin ◽

◽

Alexey E. Kontorovich ◽

Andrey M. Fomin ◽

◽

...

Keyword(s):

Seismic Data ◽

Structural Model ◽

Oil And Gas ◽

Sedimentary Cover ◽

Data Interpretation ◽

Hydrocarbon Generation ◽

Deep Drilling ◽

Middle Cambrian ◽

Seismic Surveys ◽

Gas Source

Based on geological and geophysical data, such as deep drilling, well logging, seismic surveys CDP-2D, DSS, SK-VSP a sedimentary cover structural model of the Vilyui hemisineclise to the lower Cambrian roof is constructed. According to seismic data interpretation, the ubiquitous development of the oil and gas source Kuonamka formation is predicted within the internal boundaries of the Vilyui hemisyneclise, where it formed an extensive center of hydrocarbon generation. Clinoform-built Middle Cambrian rocks (Maysky stage) overlie Kuonamka formation. The reservoirs development in the Maysky stage rocks is substantiated, a forecast map of porosity coefficients is generated.

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Features of the geological structure and oil and gas content of the shelves of the Far Eastern Seas

Georesursy ◽

10.18599/grs.2021.2.2 ◽

2021 ◽

Vol 23 (2) ◽

pp. 26-34

Author(s):

Antonina V. Stoupakova ◽

Anna A. Suslova ◽

Andrey A. Knipper ◽

Evgeniya E. Karnyushina ◽

Oleg V. Krylov ◽

...

Keyword(s):

Oil And Gas ◽

Sedimentary Cover ◽

Mineral Resources ◽

Geological Structure ◽

Gas Content ◽

Eastern Region ◽

Hydrocarbon Generation ◽

Hydrocarbon Fields ◽

Far Eastern ◽

Far Eastern Seas

Russian shelf is one of the most important areas for hydrocarbon forecast and mineral resources development. The main features of the geological structure of the shelves of the Far Eastern seas are discussed in the paper. The most promising basins on the Okhotsk shelf are located around Sakhalin island where the majority of the hydrocarbon fields have been discovered. The Bering and the Japan shelf has not been sufficiently studied by now but nevertheless has high oil and gas potential. The main focus is made on the geological and geophysical data, licensing, lithological and stratigraphic structure, seismic interpretation, oil and gas fields distribution. The structural-tectonic zoning of the entire Far Eastern region has been done in order to identify zones of deep troughs with thick sedimentary cover to predict the sources of hydrocarbon generation.

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Prospects of oil and gas potential of the Pripyat trough carbonate complex

Georesursy ◽

10.18599/grs.2019.2.110-116 ◽

2019 ◽

Vol 21 (2) ◽

pp. 110-116

Author(s):

Natalya P. Fadeeva ◽

Elena N. Poludetkina ◽

Yury A. Petrichenko

Keyword(s):

Oil And Gas ◽

Carbonate Complex ◽

Oil And Gas Exploration ◽

Oil And Gas Fields ◽

Gas Source ◽

Geological Work ◽

Gas Fields ◽

Geochemical Studies ◽

Gas Potential ◽

Carbonate Complexes

Oil-geological work in the Pripyat oil and gas basin has been going on for over 70 years; to date, more then 80 oil and gas fields have been discovered there, but due to the ever-growing need for energy consumption, work on the identification of new resources is constantly continuing. Geochemical studies of oil deposits, as well as 3D modeling of the processes of generation, emigration and accumulation of hydrocarbons, taking into account all risk factors, made it possible to identify promising objects for oil and gas exploration in the subsalt and intersalt carbonate complexes. The calculated scales of generation, emigration and accumulation of hydrocarbons, carried out as a result of geochemical and basin modeling, turned out to be comparable and showed that the oil and gas source potential of the Devonian sediments of the Pripyat trough was realized by no more than one third.

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Evaluation of Hydrocarbon Generation Using Structural and Thermal Modeling in the Thrust Belt of Kuqa Foreland Basin, NW China

Geofluids ◽

10.1155/2020/8894030 ◽

2020 ◽

Vol 2020 ◽

pp. 1-18

Author(s):

Chengfu Lyu ◽

Xixin Wang ◽

Xuesong Lu ◽

Qianshan Zhou ◽

Ying Zhang ◽

...

Keyword(s):

Source Rock ◽

Oil And Gas ◽

Thermal Evolution ◽

Foreland Basin ◽

Source Rocks ◽

Mature Stage ◽

Hydrocarbon Generation ◽

Thrust Belt ◽

Salt Layer ◽

Kuqa Foreland Basin

The Kuqa Basin is a typical foreland basin in northwest China, characterized by compressive foreland fold-and-thrust belts and a regionally distributed huge salt layer. A large number of overthrust faults, fault-related folds, and salt-related structures are formed on the thrust belt due to strong compression and structural deformation, causing difficulty in simulation of the basin. In this study, modeling of the thermal history of the complicated compressional structural profiles in the Kuqa foreland basin was successfully conducted based on the advanced “Block” function introduced by the IES PetroMod software and the latest geological interpretation results. In contrast to methods used in previous studies, our method comprehensively evaluates the influence of overthrusting, a large thick salt layer with low thermal conductivity, fast deposition, or denudation on the thermal evolution history. The results demonstrate that the hydrocarbon generation center of the Kuqa foreland basin is in the deep layers of the Kelasu thrust belt and not in the Baicheng Sag center, which is buried the deepest. A surprising result was drawn about the center of hydrocarbon generation in the Kuqa foreland basin, which, although not the deepest in Baicheng Sag, is the deepest part of the Kelasu thrust Belt. In terms of the maturity of the source rock, there are obvious temporal and spatial differences between the different structural belts in the Kuqa foreland basin, such as the early maturation of source rocks and the curbing of uplift and hydrocarbon generation in the piedmont zone. In the Kelasu thrust belt, the source rock made an early development into the low mature-mature stage and subsequently rapidly grew into a high-over mature stage. In contrast, the source rock was immature at an early stage and subsequently grew into a low mature-mature stage in the Baicheng Sag–South slope belt. The time sequence of the thermal evolution of source rocks and structural trap formation and their matching determines the different accumulation processes and oil and gas compositions in the different structural belts of the Kuqa foreland basin. The matching of the multistage tectonic activity and hydrocarbon generation determines the characteristics of the multistage oil and gas accumulation, with the late accumulation being dominant. The effective stacking of the gas generation center, subsalt structural traps, reservoir facies of fine quality, and huge, thick salt caprocks creates uniquely favorable geological conditions for gas enrichment in the Kelasu foreland thrust belt.

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