TRAPPING MECHANISMS AND THE HYDROCARBON POTENTIAL OF THE EXMOUTH PLATEAU, WESTERN AUSTRALIA

1979 ◽  
Vol 19 (1) ◽  
pp. 19
Author(s):  
A. J. Wright ◽  
T. J. Wheatley
Keyword(s):  
Hydrocarbon Potential ◽  
Hydrocarbon Generation ◽  
Sea Floor ◽  
Geological Interpretation ◽  
Exmouth Plateau ◽  
Oil Reserves ◽  
Hydrocarbon Traps ◽  
Fault Block ◽  
Gas Chimney ◽  
Seismic Sections

An interpretation of the structural configuration and hydrocarbon potential of the Exmouth Plateau has been made utilizing the results of G.S.I's 1976 Scientific Investigation (No. 10 S.L.).Seismic sections suggest sediments down to at least four seconds (two way time) below the sea floor. A prominent regional unconformity separates faulted and dipping sediments from generally flat overlying beds.Eight horizons of apparent regional importance were picked and correlated to existing well control.Structure maps were prepared for the regional unconformity and three overlying horizons, including the interpreted top of the Barrow Group. Mapping showed the main potential hydrocarbon traps to be large fault block features associated with the regional culmination of the unconformity event, and broad anticlinal drapes at top Barrow Group level. Geological interpretation suggests that the fault blocks consist of late Middle to Upper Triassic sediments, probably sandstone and shale. These sandstones could be potential reservoirs for hydrocarbons generated at depth. Seismic evidence of hydrocarbon generation includes a probable gas chimney associated with the western bounding fault of the highest fault block.The present sea floor topographic high of the Exmouth Plateau is coincident with the large drape structure embracing a foresetting package within the Barrow Group. Velocity studies over the Plateau suggest a probable lack of sand in the upper part of the Barrow Group section. Sourcing of sands in the lower part is envisaged as originating from sediments in older, underlying fault blocks. The Triassic fault blocks are considered to have the higher potential for oil reserves, but recoverable volumes are not likely to be in the 'giant' category (500 million barrels).

THE GEOLOGICAL ROLE OF THE SEARCH METHOD "WILD CAT WELLS" IN THE STUDY OF THE HYDROCARBON POTENTIAL OF THE PRIPYAT TROUGH

2021 ◽  
pp. 148-168
Author(s):  
Yaroslav G. Gribik
Keyword(s):  
Search Method ◽  
Hydrocarbon Potential ◽  
Geological Exploration ◽  
Positive Role ◽  
Oil Reserves ◽  
Hydrocarbon Traps ◽  
Deep Wells ◽  
Initial Stage ◽  
Exploratory Wells

The results of geological exploration for oil within the Elsky, Shatilkovsky, Savichsky and Petrikovsko-Shestovichsky sections of the Pripyat trough are analyzed. The analysis covers almost 70 years from the drilling of the first exploratory wells laid by the "wild cat" method to the modern comprehensive justification. During the analyzed period, from 12 to 23 deep wells were drilled with a total penetration of 42.3 thousand meters to 68.3 thousand meters in each section. The initial stage of work after the first oil inflow is characterized by a higher activity of drilling new exploratory wells, justified by the methods available at that time. The negative result of exploratory drilling in certain areas is also due to the significant fragmentation of the intrasalt perspective horizons and the areal unevenness of reservoir layers in the subsalt complex. Within the boundaries of the sites, deposits with recoverable oil reserves of no more than 450 thousand tons are established, which can be determined as a low economic efficiency of prospecting operations. However, the work has played a positive role in determining real models of hydrocarbon traps for use in the study of other sites.

scholarly journals Studies on the onshore hydrocarbon potential in East Greenland 1986-87: field work from 72° to 74°N

1987 ◽  
Vol 135 ◽  
pp. 72-81
Author(s):  
C Marcussen ◽  
F.G Christiansen ◽  
P.-H Larsen ◽  
H Olsen ◽  
S Piasecki ◽  
...  
Keyword(s):  
Thermal History ◽  
Sedimentary Basins ◽  
Field Work ◽  
Source Rocks ◽  
Hydrocarbon Potential ◽  
East Greenland ◽  
The North ◽  
Hydrocarbon Traps ◽  
Subsidence History ◽  
Tectonic Study

A study of the onshore hydrocarbon potential of central and northem East Greenland was initiated in 1986. Field work was carried out from early July to mid August covering the region between Kong Oscar Fjord and Kejser Franz Joseph Fjord (fig. 1). In 1987 field activities will continue further to the north, eventually reaching Danmarkshavn (77°N). The programme is a continuation of the 1982-83 investigations in Jameson Land (Surlyk, 1983; Surlyk et al., 1984a) and is part of a regional programme comprising petroleum geological studies of all sedimentary basins in Greenland (Larsen & Marcussen, 1985; Larsen, 1986). The aim of the two-year field study followed by laboratory analyses is: (1) to study the presence and distribution of potential hydrocarbon source rocks in the region; (2) to evaluate the thermal history and maturity pattern of the region including the thermal effect of Tertiary intrusions and volcanics; (3) to make a stratigraphic, sedimentological and tectonic study of the region with special emphasis on subsidence history, reservoir formation and potential hydrocarbon traps.

GEOLOGY, SOURCE ROCKS AND HYDROCARBON GENERATION IN THE CLARENCE-MORETON BASIN

1982 ◽  
Vol 22 (1) ◽  
pp. 5
Author(s):  
A. R. Martin ◽  
J. D. Saxby
Keyword(s):  
Vitrinite Reflectance ◽  
Source Rocks ◽  
Geochemical Data ◽  
Hydrocarbon Potential ◽  
Hydrocarbon Generation ◽  
Tectonic Events ◽  
History Of ◽  
Rock Eval ◽  
Coal Measures ◽  
Migration Pathways

The geology and exploration history of the Triassic-Cretaceous Clarence-Moreton Basin are reviewed. Consideration of new geochemical data ('Rock-Eval', vitrinite reflectance, gas chromatography of extracts, organic carbon and elemental analysis of coals and kerogens) gives further insights into the hydrocarbon potential of the basin. Although organic-rich rocks are relatively abundant, most source rocks that have achieved the levels of maturation necessary for hydrocarbon generation are gas-prone. The exinite-rich oil-prone Walloon Coal Measures are in most parts relatively immature. Some restraints on migration pathways are evident and igneous and tectonic events may have disturbed potentially well-sealed traps. Further exploration is warranted, even though the basin appears gas-prone and the overall prospects for hydrocarbons are only fair. The most promising areas seem to be west of Toowoomba for oil and the Clarence Syncline for gas.

scholarly journals Modeling and Imaging of Multiscale Geological Media: Exploding Reflection Revisited

Geosciences ◽  
2018 ◽  
Vol 8 (12) ◽  
pp. 476
Author(s):  
Evgeny Landa ◽  
Galina Reshetova ◽  
Vladimir Tcheverda
Keyword(s):  
Seismic Waves ◽  
Fractured Reservoirs ◽  
Single Shot ◽  
Middle Point ◽  
Seismic Surveys ◽  
Geological Interpretation ◽  
Time Migration ◽  
Diffraction Imaging ◽  
Heterogeneous Multiscale ◽  
Seismic Sections

Computation of Common Middle Point seismic sections and their subsequent time migration and diffraction imaging provides very important knowledge about the internal structure of 3D heterogeneous geological media and are key elements for successive geological interpretation. Full-scale numerical simulation, that computes all single shot seismograms, provides a full understanding of how the features of the image reflect the properties of the subsurface prototype. Unfortunately, this kind of simulations of 3D seismic surveys for realistic geological media needs huge computer resources, especially for simulation of seismic waves’ propagation through multiscale media like cavernous fractured reservoirs. Really, we need to combine smooth overburden with microstructure of reservoirs, which forces us to use locally refined grids. However, to resolve realistic statements with huge multi-shot/multi-offset acquisitions it is still not enough to provide reasonable needs of computing resources. Therefore, we propose to model 3D Common Middle Point seismic cubes directly, rather than shot-by-shot simulation with subsequent stacking. To do that we modify the well-known "exploding reflectors principle" for 3D heterogeneous multiscale media by use of the finite-difference technique on the base of grids locally refined in time and space. We develop scalable parallel software, which needs reasonable computational costs to simulate realistic models and acquisition. Numerical results for simulation of Common Middle Points sections and their time migration are presented and discussed.

scholarly journals Assessment of hydrocarbon potential of Jurassic and Cretaceous source rocks in the Tarnogród-Stryi area (SE Poland and W Ukraine)

2012 ◽  
Vol 63 (4) ◽  
pp. 319-333 ◽  
Author(s):  
Paweł Kosakowski ◽  
Dariusz Więcław ◽  
Adam Kowalski ◽  
Yuriy Koltun
Keyword(s):  
Organic Matter ◽  
Middle Jurassic ◽  
Sedimentary Cover ◽  
Source Rocks ◽  
Hydrocarbon Potential ◽  
Hydrocarbon Generation ◽  
Hydrocarbon Source Rock ◽  
Core Samples ◽  
Se Poland ◽  
Geochemical Parameters

Assessment of hydrocarbon potential of Jurassic and Cretaceous source rocks in the Tarnogród-Stryi area (SE Poland and W Ukraine) The Jurassic/Cretaceous stratigraphic complex forming a part of the sedimentary cover of both the eastern Małopolska Block and the adjacent Łysogóry-Radom Block in the Polish part as well as the Rava Rus'ka and the Kokhanivka Zones in the Ukrainian part of the basement of the Carpathian Foredeep were studied with geochemical methods in order to evaluate the possibility of hydrocarbon generation. In the Polish part of the study area, the Mesozoic strata were characterized on the basis of the analytical results of 121 core samples derived from 11 wells. The samples originated mostly from the Middle Jurassic and partly from the Lower/Upper Cretaceous strata. In the Ukrainian part of the study area the Mesozoic sequence was characterized by 348 core samples collected from 26 wells. The obtained geochemical results indicate that in both the south-eastern part of Poland and the western part of Ukraine the studied Jurassic/Cretaceous sedimentary complex reveals generally low hydrocarbon source-rock potential. The most favourable geochemical parameters: TOC up to 26 wt. % and genetic potential up to 39 mg/g of rock, were found in the Middle Jurassic strata. However, these high values are contradicted by the low hydrocarbon index (HI), usually below 100 mg HC/g TOC. Organic matter from the Middle Jurassic strata is of mixed type, dominated by gas-prone, Type III kerogen. In the Polish part of the study area, organic matter dispersed in these strata is generally immature (Tmax below 435 °C) whereas in the Ukrainian part maturity is sufficient for hydrocarbon generation.

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

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.

scholarly journals Applying seismic stratigraphy analysis for assessing upper Oligocene stratigraphic traps in Southeastern Cuu Long Basin

2017 ◽  
Vol 20 (K4) ◽  
pp. 48-56
Author(s):  
Chuc Dinh Nguyen ◽  
Tu Van Nguyen ◽  
Hung Quang Nguyen ◽  
Cuong Van Bui ◽  
Thanh Quoc Truong ◽  
...  
Keyword(s):  
Oil And Gas ◽  
Seismic Stratigraphy ◽  
Gas Production ◽  
Hydrocarbon Potential ◽  
Seismic Attribute ◽  
Oil And Gas Production ◽  
Attribute Analysis ◽  
Exploration Drilling ◽  
Seismic Sections ◽  
Log Interpretation

As oil and gas production has been going on over a few decades, conventional plays such as pre-Tertiary fractured basement highs and Cenozoic structural traps become more and more exhausted, and the remaining targets of the same type do not have sufficient reserves for development and production. Exploration activities in Cuu Long basin, therefore, are shifting towards more complicating types of plays which are stratigraphic traps and combination traps. Several researches were conducted in southeastern marginal slope and indicated the possibility of stratigraphic pinch-out traps with insufficient petroleum system and low hydrocarbon potential. In spite of many researches, there are still difficulties in defining the distribution and in evaluating hydrocarbon potential of these traps, so seismic stratigraphy analysis in accompanied with interpretation of seismic attribute and well logs is very necessary to support this problem. Seismic stratigraphic analysis on seismic sections, in agreement with seismic attributes’ and log analysis’ findings, show that the stratigraphic/combination traps in Oligocene C and D were formed during lowstand system tract as sigmoid-oblique clinoforms downlapping onto underlying strata in distributary mouths/delta settings. The integration of seismic attribute analysis and well log interpretation has further defined the fan-shaped distribution of these traps. Thus, using various methods, the stratigraphic traps can be better revealed. Further studies, however, need to be carried out to fully evaluate hydrocarbon potential of these stratigraphic/ combination traps, and minimize risks in exploration drilling.

The Influence of Rock Pyrolysis Parameters Correction on the Hydrocarbon Expulsion Efficiency — Taking Example of Well Xu11

2013 ◽  
Vol 848 ◽  
pp. 60-65
Author(s):  
Hai Tao Xue ◽  
Wen Hua Zhang ◽  
Shan Si Tian ◽  
Hong Yang Zhang
Keyword(s):  
Boiling Point ◽  
Carbon Number ◽  
Hydrocarbon Potential ◽  
Hydrocarbon Generation ◽  
High Carbon ◽  
The Real ◽  
Before And After ◽  
Real Value ◽  
Pyrolysis Experiment ◽  
Hydrocarbon Expulsion

In the rock pyrolysis experiment, part of the boiling point above 300°C of the high carbon number hydrocarbons and the hydrocarbon generated from pyrolysis of resin and asphaltene detected into S2, resulting in the thermolysis residual hydrocarbon "S1" is smaller than the real value, potential hydrocarbon generation of kerogen "S2" is greater than the real value. Thus using the experimental pyrolysis parameters directly calculate the hydrocarbon expulsion efficiency is greater than the real value. We used the pyrolysis parameters before and after correction, combined with the method of the restoring of original hydrocarbon potential to calculate the hydrocarbon expulsion efficiency of mudstone of Qingshankou l member of well Xu 11 in San Zhao area of Song Liao Basin. The average of the expulsion efficiency before and after the pyrolysis parameters correction are 87.4% and 66.9%. The hydrocarbon expulsion efficiency have a great difference between before and after correction, thus the pyrolysis parameters correction is particularly important in the calculation of hydrocarbon expulsion efficiency.

DETERMINATION OF THE HYDROCARBON PROSPECTIVITY OF SEDIMENTS BY HYDROGENATION

1984 ◽  
Vol 24 (1) ◽  
pp. 222 ◽  
Author(s):  
E. J. Evans ◽  
B. D. Batts
Keyword(s):  
Liquid Hydrocarbon ◽  
Land Plant ◽  
Source Rocks ◽  
Hydrocarbon Potential ◽  
Hydrocarbon Generation ◽  
Hydrocarbon Content ◽  
Hydrocarbon Maturation ◽  
Significant Difference ◽  
Recent Developments ◽  
Exploratory Wells

Recent developments in hydrogenation procedures allow the liquid hydrocarbon potential and the total liquid hydrocarbon content of source rocks to be determined directly. In essence, mild controlled hydrogenation. without the cleavage of C-C bonds, converts the recognized hydrocarbon precursors in immature source rocks, i.e. the largely aliphatic acids, alcohols, esters, etc., into the parent alkanes. These alkanes, which have a distinctive composition, are easily collected and determined in toto by routine analytical processes. Thus hydrocarbon potentials are immediately revealed.Since the bulk of Australian crudes are of land plant (humic) origin, initial investigations have been largely concentrated on vitrinites and inertinites separated from Australian coals. These studies have shown that:the formation, on hydrogenation, of alkanes with a distinctive composition is an excellent guide to sediment maturity and to hydrocarbon potential; hydrocarbon generation, although not hydrocarbon maturation, is complete when the reflectance of vitrinite in contributing sediments approximates 0.65 per cent; and no significant difference exists between the hydrocarbon potentials and the hydrocarbon content of associated inertinites and vitrinites when the reflectance of the latter is in the range 0.3 to 1.2 per cent. These findings provide a guide to basin potentials and an explanation for the unexpected prospectivity of inertinite-rich Australian sediments.Results of applying this procedure to sediment samples from exploratory wells in the Gippsland and Cooper Basins have generally followed trends seen with coal samples and confirmed the value of the method in determining hydrocarbon potentials.

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