Dynamics of lithogenesis of Phanerozoic sedimentary sequence of the Carpathian-Black Sea region in the aspect of their oil- and gas-bearing potential

2021 ◽  
Vol 1-2 (183-184) ◽  
pp. 60-75
Author(s):  
Nataliya Radkovets ◽  
Kostyantyn Hrygorchuk ◽  
Yuriy Koltun ◽  
Volodymyr Hnidets ◽  
Ihor Popp ◽  
...  
Keyword(s):  
Black Sea ◽  
Oil And Gas ◽  
Morphological Changes ◽  
Sedimentary Basins ◽  
Hydrocarbon Generation ◽  
Burial History ◽  
Reservoir Properties ◽  
Study Region ◽  
Black Sea Region ◽  
Gas Bearing

The objective of this work was to study the environments and processes of ancient sedimentation in the epi- and mesopelagic basins of the Carpathian-Black Sea region and to clarify the conditions of oil and gas basins formation within the study region as well as the main aspects of hydrocarbon generation. The burial history of the basins, some aspects of their fluid regime, issues of lithogenetic record, features of transformation of sedimentary basins into the rock-formation basins and the development of the latter during the Phanerozoic are considered. The spatial and temporal peculiarities of the evolution of epi-mesopelogic systems and their influence on the formation of oil- and gas-bearing strata within the Carpathian-Black Sea region have been studied. It has been established that in the sedimentary basins of the Carpathian-Black Sea continental margin of the Tethys Ocean during the long geological history the different intensity structural and morphological changes took place: changes of the subsidence rate of the basin bottom, inversion uplifts, sedimentation pauses, deformation of the sedimentary fill. This was reflected both in the peculiarities of the development of sedimentary environments and in the processes of substance differentiation with the formation of certain post-sedimentary mineral-structural parageneses. It was proved that discrete processes of differentiated compaction and defluidization of sediments cause a number of deformation phenomena, which can be reflected in the features of the morphology of the sedimentary basin bottom, influencing the nature of sediment transportation and accumulation. On the basis of the conducted investigations a number of practical results were obtained which will allow forming new approaches to criteria of hydrocarbons prospecting, in particular the lithophysical aspect which is concentrated on the reservoir properties of rocks; sedimentary reconstructions and the diversity of cyclicity of the studied sediments as a factor of the establishment of prospective areas, reconstruction of the burial history, which provides an information on the state of transformation of organic matter and hydrocarbons, and therefore the range of prospective depths for oil and gas occurrence.

scholarly journals Evaluation of hydrocarbons generated from the Permo-Carboniferous source rocks in Huanghua Depression of the Bohai Bay Basin, China

2018 ◽  
Vol 36 (5) ◽  
pp. 1229-1244
Author(s):  
Xiao-Rong Qu ◽  
Yan-Ming Zhu ◽  
Wu Li ◽  
Xin Tang ◽  
Han Zhang
Keyword(s):  
Oil And Gas ◽  
Source Rocks ◽  
Bohai Bay ◽  
Hydrocarbon Generation ◽  
Burial History ◽  
Bohai Bay Basin ◽  
Important Conclusion ◽  
The North ◽  
Huanghua Depression ◽  
History Of

The Huanghua Depression is located in the north-centre of Bohai Bay Basin, which is a rift basin developed in the Mesozoic over the basement of the Huabei Platform, China. Permo-Carboniferous source rocks were formed in the Huanghua Depression, which has experienced multiple complicated tectonic alterations with inhomogeneous uplift, deformation, buried depth and magma effect. As a result, the hydrocarbon generation evolution of Permo-Carboniferous source rocks was characterized by discontinuity and grading. On the basis of a detailed study on tectonic-burial history, the paper worked on the burial history, heating history and hydrocarbon generation history of Permo-Carboniferous source rocks in the Huanghua Depression combined with apatite fission track testing and fluid inclusion analyses using the EASY% Ro numerical simulation. The results revealed that their maturity evolved in stages with multiple hydrocarbon generations. In this paper, we clarified the tectonic episode, the strength of hydrocarbon generation and the time–spatial distribution of hydrocarbon regeneration. Finally, an important conclusion was made that the hydrocarbon regeneration of Permo-Carboniferous source rocks occurred in the Late Cenozoic and the subordinate depressions were brought forward as advantage zones for the depth exploration of Permo-Carboniferous oil and gas in the middle-northern part of the Huanghua Depression, Bohai Bay Basin, China.

scholarly journals GEOCHEMICAL AND GEOSTATISTICAL ASSESSMENT OF CRETACEOUS COALS AND SHALES IN SOME NIGERAIN SEDIMENTARY BASINS FOR THEIR HYDROCARBON PRONESS AND MATURITY LEVELS

2020 ◽  
Vol 1 (2) ◽  
Keyword(s):  
Source Rock ◽  
Oil And Gas ◽  
Linear Regression Analysis ◽  
Sedimentary Basins ◽  
Source Rocks ◽  
Hydrocarbon Generation ◽  
Good Source ◽  
Type Iii ◽  
Limit Value ◽  
The Impact

The Rock–Eval pyrolysis and LECO analysis for 9 shale and 12 coal samples, as well as, geostatistical analysis have been used to investigate source rock characteristics, correlation between the assessed parameters (QI, BI, S1, S2, S3, HI, S1 + S2, OI, PI, TOC) and the impact of changes in the Tmax on the assessed parameters in the Cretaceous Sokoto, Anambra Basins and Middle Benue Trough of northwestern, southeastern and northcentral Nigeria respectively. The geochemical results point that about 97% of the samples have TOC values greater than the minimum limit value (0.5 wt %) required to induce hydrocarbon generation from source rocks. Meanwhile, the Dukamaje and Taloka shales and Lafia/Obi coal are found to be fair to good source rock for oil generation with slightly higher thermal maturation. The source rocks are generally immature through sub-mature to marginal mature with respect to the oil and gas window, while the potential source rocks from the Anambra Basin are generally sub-mature grading to mature within the oil window. The analyzed data were approached statistically to find some relations such as factors, and clusters concerning the examination of the source rocks. These factors were categorized into type of organic matter and organic richness, thermal maturity and hydrocarbon potency. In addendum, cluster analysis separated the source rocks in the study area into two groups. The source rocks characterized by HI >240 (mg/g), TOC from 58.89 to 66.43 wt %, S1 from 2.01 to 2.54 (mg/g) and S2 from 148.94 to 162.52 (mg/g) indicating good to excellent source rocks with kerogen of type II and type III and are capable of generating oil and gas. Followed by the Source rocks characterized by HI <240 (mg/g), TOC from 0.94 to 36.12 wt%, S1 from 0.14 to 0.72 (mg/g) and S2 from 0.14 to 20.38 (mg/g) indicating poor to good source rocks with kerogen of type III and are capable of generating gas. Howeverr, Pearson’s correlation coefficient and linear regression analysis shows a significant positive correlation between TOC and S1, S2 and HI and no correlation between TOC and Tmax, highly negative correlation between TOC and OI and no correlation between Tmax and HI. Keywords- Cretaceous, Geochemical, Statistical, Cluster; Factor analyses.

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

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.

scholarly journals Geology and prospects of oil and gas bearing of east — Canadian continental margins

2019 ◽  
Vol 59 (4) ◽  
pp. 656-669
Author(s):  
A. Zabanbark ◽  
L. I. Lobkovsky
Keyword(s):  
Nova Scotia ◽  
Continental Margin ◽  
Late Cretaceous ◽  
Oil And Gas ◽  
Sedimentary Basins ◽  
Wide Distribution ◽  
Labrador Sea ◽  
Continental Margins ◽  
The North ◽  
Gas Bearing

At the limit of the East-Canadian continental margin there are three oil and gas regions from north to south: Labrador Sea shelves, margins of the Great Newfoundland Bank and the continental margin of Nova Scotia. In each of these distinguishing regions are a number of sedimentary basins completely plunging under the water. At the shelf of Labrador Sea distinguishing the following large sedimentary basins: Saglek, Hopdale and Havke, at the margin of Newfoundland Bank it is known the basins: Jeanne d’Arc, Flemish Pass and Orphan. At the Nova Scotia shelf there are Nova Scotian and Sable basins. It is remarkable at the lofty latitude like of Labrador Sea region the age of the productive sediments beginning from more ancient rocks (Paleozoic), than in basins situated in law latitude (Mesozoic). In consequence of this the stratigraphy diapason of oil and gas bearing of the north latitude is considerably wide. The prospect of oil and gas bearing in all region is related principally with continental slopes and turbidites sediments in its. Late Jurassic and early Cretaceous reservoirs would be the aim for deep drilling sediments. Wide distribution of late Cretaceous and early Tertiary prospects reservoirs of oil and gas is quite really so far as they are bedded in the shallow horizons. Also the prospect of oil and gas bearing at the margin of the basin is related to late Cretaceous and Tertiary sediments, to deposits of fan and diapirs salt.

scholarly journals THE PROGNOSIS OF OIL-AND-GAS BEARING OF NEAR-KERCH SHELF OF BLACK SEA BY THE RESULTS OF STRUCTURAL, GAS-GEOCHEMICAL AND THERMOMETRIC RESEARCHES

2014 ◽  
Vol 0 (1) ◽  
pp. 33-42 ◽  
Author(s):  
I.D. Bagriy ◽  
Z.Y. Voytsitskiy ◽  
M.Y. Griga ◽  
I.E. Mamyshev ◽  
S.D. Aks’om
Keyword(s):  
Black Sea ◽  
Oil And Gas ◽  
Gas Bearing

The Tolmount Field, Block 42/28d, UK North Sea

2020 ◽  
Vol 52 (1) ◽  
pp. 262-272 ◽  
Author(s):  
A. Miles ◽  
M. Allen ◽  
L. Fairweather ◽  
J. Hilton ◽  
H. Sloan ◽  
...  
Keyword(s):  
North Sea ◽  
Burial History ◽  
Reservoir Properties ◽  
Water Contact ◽  
Diagenetic Alteration ◽  
Reservoir Sandstones ◽  
Sandstone Formation ◽  
The Uk ◽  
Continental Basin ◽  
Gas Bearing

AbstractThe Tolmount Field is a lean gas condensate accumulation located in Block 42/28d of the UK Southern North Sea. The field was discovered in 2011 by well 42/28d-12, which encountered good-quality gas-bearing reservoir sandstones of the Permian Leman Sandstone Formation. The discovery was appraised in 2013 by wells 42/28d-13 and 42/28d-13Z, which logged the gas–water contact on the eastern flank of the field. The Tolmount structure is a four-way, dip-closed, faulted anticline, orientated NW to SE. The reservoir comprises mixed aeolian dune and fluvial sheetflood facies deposited within an arid continental basin. Dune sands display the best reservoir properties with porosities around 22% and permeabilities exceeding 100 mD. Only minor diagenetic alteration has occurred, primarily in the form of grain-coating illite. Superior reservoir quality is observed at Tolmount compared to adjacent areas, due to the preservation of dune facies, a hypothesized early gas emplacement and a relatively benign burial history. Current mapped gas initially-in-place estimates for the field are between 450 bcf and 800 bcf, with an estimated recovery factor between 70 and 90%. An initial four-well development is planned, with first gas expected in 2020.

scholarly journals Effect of Invasive Rhododendron ponticum L. on Natural Regeneration and Structure of Fagus orientalis Lipsky Forests in the Black Sea Region

Forests ◽  
2020 ◽  
Vol 11 (5) ◽  
pp. 603
Author(s):  
Zdeněk Vacek ◽  
Stanislav Vacek ◽  
Derya Eşen ◽  
Oktay Yildiz ◽  
Jan Král ◽  
...  
Keyword(s):  
Black Sea ◽  
Natural Regeneration ◽  
The Black Sea ◽  
Beech Forests ◽  
Study Region ◽  
Fagus Orientalis ◽  
Black Sea Region ◽  
Rhododendron Ponticum ◽  
Tree Layer ◽  
Fagus Orientalis Lipsky

Biological invasions threaten global biodiversity and forest ecosystems; therefore, it is necessary to use appropriate strategies for combating the spread of invasive species. Natural regeneration of eastern beech (Fagus orientalis Lipsky) is considerably limited by an aggressive invasive shrub, pontic rhododendron (Rhododendron ponticum L.), in the Black Sea Region of Turkey. Therefore, the future character of the region’s forests is uncertain. The aim of this research was to evaluate the structure of beech forests with different management regimes of rhododedron and to determine the interaction among tree layer, rhododendron cover, and natural regeneration in Düzce Province using the FieldMap technology. The following variants of forests were compared: without intervention (control) and three and six years after rhododendron clearance. The results showed that tree density ranged between 175–381 trees ha−1 and stand volume between 331–589 m3 ha−1. The horizontal structure of the tree layer was mostly random, and the spatial pattern of natural regeneration was aggregated. Recruit density and height in the beech stands were significantly differentiated due to the influence of presence or absence of invasive rhododendron. Rhododendron cover ranged between 81%–97%, and woody stems amounted to 72,178–86,884 ha−1 in unmanaged forests. Canopy in the overstory did not have a significant effect on the density of regeneration and rhododendron cover. Tree layer had a significant negative influence on natural regeneration within a 4 m radius on the plots without rhododendron. However, on the plots with dense rhododendron cover, tree layer had a positive influence on regeneration within a 1.5 m radius. Natural regeneration density was significantly higher when rhododendron was cleared than the plots without intervention. On the plots without woody clearance, there was an insufficient regeneration (113–619 recruits ha−1); however, they had higher mean height compared to the sites without rhododendron. After three and six years of rhododendron clearance, the numbers of recruits in natural regeneration were 63,981 ha−1 and 105,075 ha−1, respectively. In conclusion, invasive spread of rhododendron was a limiting factor of the prosperous regeneration and tree species diversity, and manual clearance of rhododendron is recommended in managed beech forests of the study region.

Sign in / Sign up

Export Citation Format

Share Document