EXPLORATION RESULTS, HYDROCARBON POTENTIAL AND FUTURE STRATEGIES FOR THE NORTHERN GALILEE BASIN

1993 ◽  
Vol 33 (1) ◽  
pp. 280 ◽  
Author(s):  
P.J. Hawkins ◽  
P.M. Green
Keyword(s):  
Vitrinite Reflectance ◽  
Immature Stage ◽  
Thermal Modelling ◽  
Hydrocarbon Potential ◽  
Hydrocarbon Generation ◽  
Reservoir Rocks ◽  
Stratigraphic Evolution ◽  
Coal Measures ◽  
Exploration Activity ◽  
Reflectance Data

Exploration activity in the northern Galilee Basin has been sporadic and is still at an immature stage. Recent geological investigations by the Queensland Department of Resource Industries have brought about a better understanding of the geological setting and stratigraphic evolution of the basin. These investigations also identified key source and reservoir units, determined maturation trends and delineated areas with hydrocarbon potential. The geological results indicate that the Aramac Coal Measures and Betts Creek beds contain the most favourable source and reservoir rocks. Thermal modelling of vitrinite reflectance data suggests that various parts of the basin reached maturity for hydrocarbon generation at different times. Integration of the geological results and thermal modelling has enabled exploration concepts to be developed for the basin. Application of these concepts has highlighted areas along the western margin of the Koburra Trough and eastern Maneroo Platform, and areas adjacent to the Cork Fault and the Wetherby Structure in the Lovelle Depression that warrant further exploration.

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 Quantifying Multiple Erosion Events in the Distal Sector of the Northern Alpine Foreland Basin (North-Eastern Switzerland), by Combining Basin Thermal Modelling with Vitrinite Reflectance and Apatite Fission Track Data

Geosciences ◽  
2021 ◽  
Vol 11 (2) ◽  
pp. 62
Author(s):  
Silvia Omodeo-Salé ◽  
Yanis Hamidi ◽  
Diego Villagomez ◽  
Andrea Moscariello
Keyword(s):  
Vitrinite Reflectance ◽  
Foreland Basin ◽  
Thermal Modelling ◽  
North Eastern ◽  
Northern Alpine Foreland ◽  
Alpine Foreland ◽  
Alpine Foreland Basin ◽  
Stratigraphic Evolution ◽  
Reflectance Data ◽  
Modelling Approach

This work quantifies the amount of erosion associated with the Cretaceous and Miocene erosional unconformities recognised in the distal part of the Northern Alpine Foreland Basin (NAFB), north-eastern Switzerland. To achieve this goal, the basin thermal modelling approach is applied, calibrated by two different sets of data collected in previous studies: vitrinite reflectance (%Ro) and the temperature estimated from apatite fission tracks (AFT) data modelling. The novelty of this approach is the possibility to constrain the timing and magnitude of multiple erosion events by integrating thermal modelling with thermochronologic data. Combining these two methods allows the erosional events to be separated which would not be possible using only irreversible paleothermometers, such as vitrinite reflectance data. Two scenarios were tested, based on the data of two published thermochronology studies. For the Cretaceous unconformity, similar results are obtained for the two scenarios, both indicating that the deposition and the subsequent complete erosion of Lower Cretaceous deposits, in the order of 500–1300 m, depending on the area, are necessary, in order to attain the temperatures estimated by the thermal history modelling of AFT data. Thus, a depositional hiatus for this period is not likely. For the Miocene-Quaternary unconformity, the magnitude of erosion calculated for the two scenarios differs by 300–1400 m, depending on the AFT data considered. The two scenarios lead to a different evaluation of the subsidence and uplift rate of the study area, thus to a different interpretation of the tectono-stratigraphic evolution of this distal sector of the NAFB.

scholarly journals Coal rank (vitrinite reflectance) data for Cretaceous/Tertiary coal measures in the Grande Cache and Hinton areas, Alberta

1996 ◽  
Author(s):  
W D Kalkreuth ◽  
W Langenberg ◽  
M E McMechan ◽  
M A Tomica ◽  
W McDougall ◽  
...  
Keyword(s):  
Vitrinite Reflectance ◽  
Coal Rank ◽  
Coal Measures ◽  
Reflectance Data

Thermal History and Hydrocarbon Maturity Study in the Norton Basin, Alaska

1992 ◽  
Vol 10 (6) ◽  
pp. 402-421 ◽  
Author(s):  
Z. Yu ◽  
Y. Li ◽  
I. Lerche
Keyword(s):  
Fluid Flow ◽  
Late Miocene ◽  
Thermal Gradient ◽  
Vitrinite Reflectance ◽  
Hydrocarbon Generation ◽  
One Dimensional ◽  
Thermal Peak ◽  
Initial Stage ◽  
History Of ◽  
Reflectance Data

Two COST wells in the Norton Basin of Alaska were examined using a one-dimensional quantitative dynamic model (1-D). By inversion of vitrinite reflectance data with the present day thermal gradient in the basin, the paleothermal history of the basin was reconstructed and showed two high thermal peaks, one during the initial stage of basin development (60–50 MaBP) and the other at late Miocene (15–5 MaBP). The early thermal peak corresponded to thinning of the lithosphere and subsidence with upwelling of the hot asthenosphere, and the more recent thermal high was caused by the subsidence and volcanic activity during late Miocene. The Norton Basin is thermally mature with hydrocarbon generation occurring in 15–2 MaBP. Modeling the fluid flow and geopressure development using a two-dimensional fluid flow/compaction model in the basin shows that the directions of fluid movement are both vertical and towards the Yukon Horst, a main horst structure in the basin, suggesting that the hydrocarbons might accumulate in structures around the Yukon Horst and in stratigraphic traps within the basin, which are expected to be common because of the depositional variation of the various facies.

scholarly journals Geochemical Evaluation of the Cretaceous Mudrocks and Sandstones (Wackes) in the Southern Bredasdorp Basin, Offshore South Africa: Implications for Hydrocarbon Potential

Minerals ◽  
2020 ◽  
Vol 10 (7) ◽  
pp. 595
Author(s):  
Temitope Love Baiyegunhi ◽  
Kuiwu Liu ◽  
Oswald Gwavava ◽  
Nicola Wagner ◽  
Christopher Baiyegunhi
Keyword(s):  
South Africa ◽  
Oil And Gas ◽  
Vitrinite Reflectance ◽  
Source Rocks ◽  
Geochemical Data ◽  
Minor Amount ◽  
Hydrocarbon Potential ◽  
Hydrocarbon Generation ◽  
Thermal Maturity ◽  
The Mean

The southern Bredasdorp Basin, off the south coast of South Africa, is only partly understood in terms of its hydrocarbon potential when compared to the central and northern parts of the basin. Hydrocarbon potential assessments in this part of the basin have been limited, perhaps because the few drilled exploration wells were unproductive for hydrocarbons, yielding trivial oil and gas. The partial integration of data in the southern Bredasdorp Basin provides another reason for the unsuccessful oil and gas exploration. In this study, selected Cretaceous mudrocks and sandstones (wacke) from exploration wells E-AH1, E-AJ1, E-BA1, E-BB1 and E-D3 drilled in the southern part of the Bredasdorp Basin were examined to assess their total organic carbon (TOC), thermal maturity, organic matter type and hydrocarbon generation potential. The organic geochemical results show that these rocks have TOC contents ranging from 0.14 to 7.03 wt.%. The hydrogen index (HI), oxygen index (OI), and hydrocarbon index (S2/S3) values vary between 24–263 mg HC/g TOC, 4–78 mg CO2/g TOC, and 0.01–18 mgHC/mgCO2 TOC, respectively, indicating predominantly Type III and IV kerogen with a minor amount of mixed Type II/III kerogen. The mean vitrinite reflectance values vary from 0.60–1.20%, indicating that the samples are in the oil-generation window. The Tmax and PI values are consistent with the mean vitrinite reflectance values, indicating that the Bredasdorp source rocks have entered the oil window and are considered as effective source rocks in the Bredasdorp Basin. The hydrocarbon genetic potential (SP), normalized oil content (NOC) and production index (PI) values all indicate poor to fair hydrocarbon generative potential. Based on the geochemical data, it can be inferred that most of the mudrocks and sandstones (wackes) in the southern part of the Bredasdorp Basin have attained sufficient burial depth and thermal maturity for oil and gas generation potential.

Hydrocarbon Generative Properties and Maturity of Cretaceous and Eocene Sediments in the Middle Kura Depression, Azerbaijan

2021 ◽  
Author(s):  
Shahin Khosrov Akhundov ◽  
Mushfig Farhad Tagiyev ◽  
Arastun Ismail Khuduzade ◽  
Natig Namig Aliyev
Keyword(s):  
Organic Matter ◽  
Brown Coal ◽  
Lower Cretaceous ◽  
Vitrinite Reflectance ◽  
Sedimentary Cover ◽  
Hard Coal ◽  
Marine Origin ◽  
Formation Conditions ◽  
Lesser Caucasus ◽  
Reflectance Data

Abstract Meso-Cenozoic sedimentary cover in the Middle Kura depression located between the Greater and Lesser Caucasus mountain structures contains numerous oil accumulations. According to studies in the Cretaceous and Paleogene strata, sedimentary organic matter is of mixed clastic-marine origin. Moderate amounts of organic matter have been recorded in the Eocene sediments (on average 0.70%), in the Upper and Lower Cretaceous average values made up 0.39% и 0.42%, respectively. Analysis of bitumoid composition suggests that in a number of areas bitumoids have experienced a widespread movement across the sedimentary strata. The results of measurements on isolated samples indicate that the Cretaceous strata have only advanced to the initial hard-coal stage of organic transformation (0.48-0.55%Ro). On vitrinite reflectance data the Eocene deposits in studied areas of the Middle Kura depression have reached initial (brown-coal) stage of catagenetic transformation (±0.48Ro%; est. paleotemperature of 85°C). Nonetheless, analysis of formation conditions of commercial HC accumulations found earlier in the Eocene strata allows considering them the most prospective in the Middle Kura depression.

scholarly journals Thermal Maturation Regime Revisited in the Dongying Depression, Bohai Bay Basin, East China

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-17
Author(s):  
Haiping Huang ◽  
Hong Zhang ◽  
Zheng Li ◽  
Mei Liu
Keyword(s):  
Organic Geochemistry ◽  
Vitrinite Reflectance ◽  
Source Rocks ◽  
East China ◽  
Burial Depth ◽  
Bohai Bay ◽  
Hydrocarbon Generation ◽  
Bohai Bay Basin ◽  
Dongying Depression ◽  
Hydrocarbon Maturation

To the accurate reconstruction of the hydrocarbon generation history in the Dongying Depression, Bohai Bay Basin, East China, core samples of the Eocene Shahejie Formation from 3 shale oil boreholes were analyzed using organic petrology and organic geochemistry methods. The shales are enriched in organic matter with good to excellent hydrocarbon generation potential. The maturity indicated by measured vitrinite reflectance (%Ro) falls in the range of 0.5–0.9% and increases with burial depth in each well. Changes in biomarker and aromatic hydrocarbon isomer distributions and biomarker concentrations are also unequivocally correlated with the thermal maturity of the source rocks. Maturity/depth relationships for hopanes, steranes, and aromatic hydrocarbons, constructed from core data indicate different well locations, have different thermal regimes. A systematic variability of maturity with geographical position along the depression has been illustrated, which is a dependence on the distance to the Tanlu Fault. Higher thermal gradient at the southern side of the Dongying Depression results in the same maturity level at shallower depth compared to the northern side. The significant regional thermal regime change from south to north in the Dongying Depression may exert an important impact on the timing of hydrocarbon maturation and expulsion at different locations. Different exploration strategies should be employed accordingly.

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