scholarly journals Paleogeothermal and paleotectonic reconstructions based on vitrinite thermometry data (on the example of the upper paleozoic deposits of the Dnieper-Donets depression and adjacent areas of Donbass)

2021 ◽  
Vol 43 (3) ◽  
pp. 82-105
Author(s):  
A. V. Ivanova ◽  
V. B. Gavryltsev
Keyword(s):  
Organic Matter ◽  
Thermal History ◽  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Regional Distribution ◽  
Distribution Patterns ◽  
Tectonic Structures ◽  
Upper Paleozoic ◽  
Coal Organic Matter ◽  
Paleotectonic Reconstructions

The article is devoted to paleogeothermal and paleotectonic reconstructions based on the results of processing the vitrinite reflectance data array of coal organic matter of the Upper Paleozoic sediments from the Don-Dnieper Downwarp (within the Dnieper-Donets Depression and adjacent areas of Donbass). It was found that paleogeothermal parameters changed under the influence of geotectonic, magmatic and lithofacies formation conditions of the Upper Paleozoic deposits. Analysis of changes and regularities distribution of paleogeothermal characteristics made it possible to assess the evolution of the thermal field, changes in the tectonic movements character, to identify the role of volcanism, deep faults geodynamics, lithosphere thickness in the thermal history of the region under study. It is shown that with the help of paleostructural analysis, based on data on the thermal maturity degree of coal organic matter, it is possible to judge the activity changes of tectonic structures in time, the formation sequence, to establish the amplitudes of their mutual displacement and rank according to oil and gas potential. Based on the results of the work, maps of the paleogeothermal gradients distribution and the amplitudes of rock masses vertical displacements were constructed. The presented maps should be considered as a universal information material that can be used to determine the features of the regional distribution of the above parameters, as well as become an important tool in the study of tectonic and thermal history, identification changes trends and distribution patterns of paleo­geothermal characteristics.

Accumulation Factors Analysis of Coal-Bearing Strata Shale Gas in Qinshui Basin

2013 ◽  
Vol 868 ◽  
pp. 121-124 ◽  
Author(s):  
Jun Yuan ◽  
Yan Bin Wang ◽  
Xin Zhang ◽  
Jing Jing Fan ◽  
Pei Xue
Keyword(s):  
Organic Matter ◽  
Mineral Composition ◽  
Shale Gas ◽  
Vitrinite Reflectance ◽  
Qinshui Basin ◽  
Factors Analysis ◽  
Upper Paleozoic ◽  
Organic Matter Type ◽  
Organic Matter Abundance

The Shanxi and Taiyuan formations in Permo-Carboniferous of upper Paleozoic Erathem of Qinshui Basin, not only has abundant coal and CBM resources, also has a lot of shales. By analyzing the shale thickness, organic matter type, organic matter abundance, vitrinite reflectance, mineral composition of the Permo-Carboniferous coal-bearing strata, considered that the shale thickness of coal-bearing strata in the Qinshui Basin is larger, the organic matter abundance is general, but maturity is high and full of rich brittle mineral. It is in favor of late fracturing.

COAL AS A SOURCE OF OIL AND GAS: A CASE STUDY FROM THE BASS BASIN, AUSTRALIA

2003 ◽  
Vol 43 (1) ◽  
pp. 117 ◽  
Author(s):  
C.J. Boreham ◽  
J.E. Blevin ◽  
A.P. Radlinski ◽  
K.R. Trigg
Keyword(s):  
Organic Matter ◽  
Oil And Gas ◽  
Middle Eocene ◽  
Vitrinite Reflectance ◽  
Mineral Resources ◽  
Sedimentary Basins ◽  
Source Rocks ◽  
Gas Generation ◽  
Australian Context ◽  
Effective Source

Only a few published geochemical studies have demonstrated that coals have sourced significant volumes of oil, while none have clearly implicated coals in the Australian context. As part of a broader collaborative project with Mineral Resources Tasmania on the petroleum prospectivity of the Bass Basin, this geochemical study has yielded strong evidence that Paleocene–Eocene coals have sourced the oil and gas in the Yolla, Pelican and Cormorant accumulations in the Bass Basin.Potential oil-prone source rocks in the Bass Basin have Hydrogen Indices (HIs) greater than 300 mg HC/g TOC. The coals within the Early–Middle Eocene succession commonly have HIs up to 500 mg HC/g TOC, and are associated with disseminated organic matter in claystones that are more gas-prone with HIs generally less than 300 mg HC/g TOC. Maturity of the coals is sufficient for oil and gas generation, with vitrinite reflectance (VR) up to 1.8 % at the base of Pelican–5. Igneous intrusions, mainly within Paleocene, Oligocene and Miocene sediments, produced locally elevated maturity levels with VR up to 5%.The key events in the process of petroleum generation and migration from the effective coaly source rocks in the Bass Basin are:the onset of oil generation at a VR of 0.65% (e.g. 2,450 m in Pelican–5);the onset of oil expulsion (primary migration) at a VR of 0.75% (e.g. 2,700–3,200 m in the Bass Basin; 2,850 m in Pelican–5);the main oil window between VR of 0.75 and 0.95% (e.g. 2,850–3,300 m in Pelican–5); and;the main gas window at VR >1.2% (e.g. >3,650 m in Pelican–5).Oils in the Bass Basin form a single oil population, although biodegradation of the Cormorant oil has resulted in its statistical placement in a separate oil family from that of the Pelican and Yolla crudes. Oil-to-source correlations show that the Paleocene–Early Eocene coals are effective source rocks in the Bass Basin, in contrast to previous work, which favoured disseminated organic matter in claystone as the sole potential source kerogen. This result represents the first demonstrated case of significant oil from coal in the Australian context. Natural gases at White Ibis–1 and Yolla–2 are associated with the liquid hydrocarbons in their respective fields, although the former gas is generated from a more mature source rock.The application of the methodologies used in this study to other Australian sedimentary basins where commercial oil is thought to be sourced from coaly kerogens (e.g. Bowen, Cooper and Gippsland basins) may further implicate coal as an effective source rock for oil.

scholarly journals Burial history, thermal history and hydrocarbon generation modelling of the Jurassic source rocks in the basement of the Polish Carpathian Foredeep and Outer Carpathians (SE Poland)

2012 ◽  
Vol 63 (4) ◽  
pp. 335-342 ◽  
Author(s):  
Paweł Kosakowski ◽  
Magdalena Wróbel
Keyword(s):  
Organic Matter ◽  
Thermal History ◽  
Vitrinite Reflectance ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Thermal Maturity ◽  
Burial History ◽  
Se Poland ◽  
Carpathian Foredeep ◽  
Outer Carpathians

Burial history, thermal history and hydrocarbon generation modelling of the Jurassic source rocks in the basement of the Polish Carpathian Foredeep and Outer Carpathians (SE Poland)Burial history, thermal maturity, and timing of hydrocarbon generation were modelled for the Jurassic source rocks in the basement of the Carpathian Foredeep and marginal part of the Outer Carpathians. The area of investigation was bounded to the west by Kraków, to the east by Rzeszów. The modelling was carried out in profiles of wells: Będzienica 2, Dębica 10K, Góra Ropczycka 1K, Goleszów 5, Nawsie 1, Pławowice E1 and Pilzno 40. The organic matter, containing gas-prone Type III kerogen with an admixture of Type II kerogen, is immature or at most, early mature to 0.7 % in the vitrinite reflectance scale. The highest thermal maturity is recorded in the south-eastern part of the study area, where the Jurassic strata are buried deeper. The thermal modelling showed that the obtained organic matter maturity in the initial phase of the "oil window" is connected with the stage of the Carpathian overthrusting. The numerical modelling indicated that the onset of hydrocarbon generation from the Middle Jurassic source rocks was also connected with the Carpathian thrust belt. The peak of hydrocarbon generation took place in the orogenic stage of the overthrusting. The amount of generated hydrocarbons is generally small, which is a consequence of the low maturity and low transformation degree of kerogen. The generated hydrocarbons were not expelled from their source rock. An analysis of maturity distribution and transformation degree of the Jurassic organic matter shows that the best conditions for hydrocarbon generation occurred most probably in areas deeply buried under the Outer Carpathians. It is most probable that the "generation kitchen" should be searched for there.

Shale Gas Resources Evaluation of the Songliao Basin

2014 ◽  
Vol 508 ◽  
pp. 129-132
Author(s):  
Xin Zhang ◽  
Jun Yuan ◽  
Pei Xue ◽  
Jing Jing Fan ◽  
Jin Wang
Keyword(s):  
Organic Matter ◽  
Mineral Composition ◽  
Shale Gas ◽  
Upper Cretaceous ◽  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Songliao Basin ◽  
Resources Evaluation ◽  
Organic Matter Type ◽  
Organic Matter Abundance

The Qingshankou and Nenjiang group in upper cretaceous of Songliao basin is a set of dark shale. Analyze the shale thickness, organic matter type, organic matter abundance, vitrinite reflectance, mineral composition of the permo-carboniferous coal-bearing strata. Consider that the thickness of shale in the Songliao basin is larger, despite the organic matter abundance is good, but maturity is lower, less of the formation of oil and gas.

Characteristics of the Overpressure Resulted from Hydrocarbon Generation

2013 ◽  
Vol 295-298 ◽  
pp. 2707-2710
Author(s):  
Hai Yan Hu ◽  
Hui Wang
Keyword(s):  
Organic Matter ◽  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Junggar Basin ◽  
Hydrocarbon Generation ◽  
Sonic Velocity ◽  
Gas Generation

Overpressure is often encountered in the Jurassic tight sandstones in the central Junggar Basin. In this studt, a new mechanism of overpressure formation related to gas generation is proposed. Organic-rich mudstones have sonic velocity well-line reserves but their densities continue to increase in the over-compacted mudstone system resulting in the overpressure development during the conversion of the organic matter to oil and gas. The top of the overpressure zone correlates with the depth required for a large quantity of gas generation in which the vitrinite reflectance (Ro) is about 0.7%, showing that the overpressure in organic-rich mudstones is closely associated with gas generation.

scholarly journals MATURE ZONE OF ORGANIC MATTER AND OIL AND GAS PROCESS OF CUU LONG BASIN

2009 ◽  
Vol 12 (6) ◽  
pp. 60-72
Author(s):  
Luan Thi Bui
Keyword(s):  
Organic Matter ◽  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Gas Oil ◽  
Lower Oligocene ◽  
Upper Oligocene ◽  
Geochemical Parameters ◽  
Wet Gas ◽  
Rock Eval ◽  
Mature Process

Geochemical parameters used popularly to define the level of maturation of organic matter are a vitrinite reflectance % Ro) combined with Tmax value defined at the peak Pic S2 by Pyrolysis (Rock-Eval). Moreover, model TTI method of Lopatin and Waple is applied to define the level of maturation of organic matter at any point where there is no well. By this way, mature process of organic matter will be estimated generally for a whole of study area. Results are that organic matters of lower Oligocene and upper Eocene formation and the bottom of upper Oligocene formation provide essentially oil and gas of Cuu Long basin. The bottom of lower Oligocene and the top of Eocene formation supplement wet and Condensat. Eocene formation at the depressions especially in the east and north BachHo is the dry gas. Oil and gas generated and migrated into traps occurred from early Miocene, but very intensively generated and migrated in period of Pliocene + Quaternary times. At the same time, the traps always are supplemented the wet gas, condensate and dry gas from Eocene formation.

scholarly journals Visean palaeoincisions as centers of fluid-generation in the Kama coal basin

Georesursy ◽  
2021 ◽  
Vol 23 (2) ◽  
pp. 67-72
Author(s):  
Iskra F. Yusupova ◽  
Natalia P. Fadeeva ◽  
Leyla A. Abukova
Keyword(s):  
Organic Matter ◽  
Oil And Gas ◽  
Fluid Dynamic ◽  
Dynamic Heterogeneity ◽  
Coal Basin ◽  
Coal Beds ◽  
Area Distribution ◽  
Coal Organic Matter ◽  
Host Rocks

The paper considers palaeoincisions in the Turnean limestones of the Volga-Ural basin, made by alluvial-deluvial sediments of the Visean age and containing interlayers of coals. Processes occurring in these sediments (catagenic reduction of thickness of coal beds and coal-bearing mudstones, aggressive influence of products of defluidization of coal organic matter on the host rocks, etc.) strengthen the fluid dynamic heterogeneity of intracrustal deposits and contribute to emigration of hydrocarbons (HC). The main oil-and-gas-generating strata in the Carboniferous section include rocks of the Tournaisian stage and the Bobrikovsky horizon of the Viseian stage. Palaeoincisions, along with the area distribution of Viseian coals, can be considered as centers of fluid generation, including liquid and gas HC.

scholarly journals Source rock characteristics and hydrocarbon generation potential in Brunei-Muara district, Brunei Darussalam: a comparative case study from selected Miocene-Quaternary formations

2021 ◽  
Vol 11 (4) ◽  
pp. 1679-1703
Author(s):  
Liyana Nadiah Osli ◽  
Mohamed Ragab Shalaby ◽  
Md. Aminul Islam
Keyword(s):  
Organic Matter ◽  
Source Rock ◽  
Vegetation Index ◽  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Rock Properties ◽  
Comparative Case Study ◽  
Hydrocarbon Generation ◽  
Brunei Darussalam ◽  
Potential Source Rock

AbstractA comparative analysis on source rock properties has been carried out on the Miocene-Pliocene formations as well as the Quaternary terrace deposits using Rock–Eval pyrolysis results and organic petrography as well as some biomarkers results. Samples were obtained from outcrops of the Quaternary terrace deposits, Pliocene-aged Liang Formation together with the Miocene Miri and Setap Shale formations in Brunei-Muara district, with sample lithologies ranging from coal, coaly shale, shale and lignitic sand. High total organic carbon (TOC) and S2 values ranging from 41.8 to 62.4% and 7.40 mg HC/g rock to 122 mg HC/g rock, respectively, are identified in coals of the terrace deposit, Liang and Miri formations, making these as the best potential source rock due to the “good to excellent” generating potential. Meanwhile, a “fair to poor” potential is exhibited for the coaly shale, shale and lignitic sand samples as a result of their low TOC, HI and S2 values. The organic matter is composed of kerogen type III (gas prone) and type II-III (mixed oil and gas prone). Organic matter in all studied formations originate from a terrestrial-source, as proven by the abundance of huminite. Organic petrographical and biomarkers studies suggest that the coals and lignitic sand samples were deposited in a mangrove-type mire in a lower delta setting, under oxic and limnic to limnotelmatic conditions, except sample DD2-1, which is deposited in a less water-saturated environment. The samples display the presence of bi-modal and normal distribution of n-alkanes. For all of the samples, the dominating plant types in the palaeomire are of soft, herbaceous plants and this is supported by the low vegetation index and moderate Paq values. All the studied samples are thermally immature to early mature, as exhibited by the Tmax values that range from 300 to 437 °C and vitrinite reflectance readings of 0.22% to 0.46%.

scholarly journals Hydrocarbon Source Rock Potential of the Lacustrine Black Shale Unit, Mamfe Basin, Cameroon, West Africa

2016 ◽  
Vol 5 (2) ◽  
pp. 217 ◽  
Author(s):  
NJOH Olivier Anoh ◽  
NJIE Sarah Mesanga
Keyword(s):  
Organic Matter ◽  
Source Rock ◽  
Black Shale ◽  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Hydrocarbon Exploration ◽  
Hydrocarbon Source Rock ◽  
Sedimentary Fill ◽  
Kerogen Pyrolysis ◽  
Rock Eval

The potential for conventional and/or unconventional hydrocarbon exploration requires the presence of organic-rich, thermally mature rock units containing oil or gas-prone kerogen. Thick black, organic rich shale intervals are well exposed along roadside cuts and river banks at several localities in the eastern part of the Mamfe Basin. Earlier described as anoxic lake bottom deposits, these fine grained rocks constitute the probable pod of active source rock in this basin and belonging to the middle stratigraphic unit of the three that make up the basin’s sedimentary fill. Samples collected from representative outcrop sections (Etoko mile 21, Bachuo Ntai, and Satom Bridge) in the study area were subjected to geochemical analytic techniques; Total Organic Carbon (TOC), Rock-Eval Pyrolysis and Vitrinite reflectance (%Ro) values were calculated. TOC data obtained range from 1.06% to 16.10% indicating good to excellent hydrocarbon generative potentials, Rock-Eval Pyrolysis data plotted along Kerogen Types I, II and III with oil and gas generative potentials. 4 out of 9 samples fall within the oil window from the calculated %Ro while temperatures corresponding to the peak of kerogen pyrolysis (Tmax) and Production Index (PI) for the 9 samples range from 398oC to 463oC indicating that the organic matter (OM) are immature to post mature.The black shale unit of this part of the basin therefore contains very high amounts of good to excellent quality of thermally matured organic matter which can produce and expel oil and gas respectively.

scholarly journals Geochemical characteristics of terrestrial organic matter in the Upper Paleozoic complex of the Vilyui syneclise and some features of its transformation under thermobaric conditions at great depths

Georesursy ◽  
2019 ◽  
Vol 21 (4) ◽  
pp. 77-84
Author(s):  
Kirill V. Dolzhenko ◽  
Alexander N. Fomin ◽  
Vasily N. Melenevsky
Keyword(s):  
Organic Matter ◽  
Vitrinite Reflectance ◽  
Sharp Decrease ◽  
Organic Carbon Content ◽  
Depth Range ◽  
Terrestrial Organic Matter ◽  
Deep Well ◽  
Upper Paleozoic ◽  
Type Composition ◽  
Thermobaric Conditions

A combination of geochemical methods were used to study organic matter from Permian rocks in the central part of the Vilyui syneclise (East Siberia) penetrated by the Srednevilyuiskaya-27 ultra-deep well in the depth range of 3370-6458 m. This study discusses variations in the pyrolysis indices (HI, Tmax), hydrocarbon type content (hydrocarbons-resins-asphaltenes), vitrinite reflectance (R0vt, %), organic carbon content (Corg), as well as some trends in the saturated and aromatic hydrocarbon compositions of bitumen extracts from the Upper Paleozoic rocks. Below a depth of about 4.5 km (late mesocatagenesis), the hydrocarbon type composition is characterized by a sharp decrease in the content of asphaltenes from < 30 % (at 4.5-5.0 km) to < 15 % (at 5.0-5.5 km), which are not detected at greater depth. In turn, the resins became the dominant constituent (~ 50-70 %), whereas hydrocarbons account for < 20 % at depths down to 5 km and < 40 % at greater depth. These depths are also characterized by a predominance of saturated hydrocarbons over aromatic compounds with a decrease in the relative contents of high molecular weight compounds in both fractions, as indicated by mass chromatograms. The hydrocarbon index (HI) of organic matter decreases to the first tens from the depth of 4.9 km and to the bottomhole (6519 m); the temperature of the maximum hydrocarbon yield (Tmax) varies between 570-580 °C, showing a slightly increasing trend. Our results show that the generative potential of organic matter from the rocks within the studied depth range (4.9-6.5 km) has been exhausted and that the terrestrial organic matter undergoes significant changes under severe temperature and pressure conditions at great depths.

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