Source rock evaluation and thermal maturity the Upper Cretaceous rocks in Abu El Gharadig Basin, Egypt: Insights to the petroleum system

2021 ◽  
Vol 302 (3) ◽  
pp. 263-297
Author(s):  
Esam A. Abd El Gawad ◽  
Walid A. Makled ◽  
Ahmed S. Mousa ◽  
Tarek Y. El Hariri ◽  
Doaa A. Mousa ◽  
...  
Keyword(s):  
Source Rock ◽  
Upper Cretaceous ◽  
Petroleum System ◽  
Thermal Maturity ◽  
Source Rock Evaluation

Petroleum Geologic Elements and Petroleum Systems in the Northern Apennines Basin

2012 ◽  
Vol 616-618 ◽  
pp. 935-938
Author(s):  
Hai Yan Hu ◽  
Song Lu ◽  
Hang Zhou Xiao
Keyword(s):  
Source Rock ◽  
Upper Cretaceous ◽  
Petroleum System ◽  
Northern Apennines ◽  
Late Triassic ◽  
Petroleum Systems ◽  
Italian Peninsula

The Northern Apennines lies in the northern Italian Peninsula. The basin has the formation of Mesozoic-Cenozoic depocentries. The source rock is Emma limestone and Late Triassic source rock, which generated at the depth of 5-7 km. The reservoir included the Upper Cretaceous-Eocene Scaglia Formation and Liassic Noriglio Limestone. The seal included Scaglia Cinerea Formation, Cerro Marls Formation and unconformity upper marls. The petroleum systems are The Emma Petroleum System and Marnoso Petroleum System.

scholarly journals Lower Cretaceous source rock evaluation and thermal maturity evolution of the Chagan depression, Inner Mongolia, Northern China

2017 ◽  
Vol 35 (4) ◽  
pp. 482-503 ◽  
Author(s):  
Yinhui Zuo ◽  
Rongcai Song ◽  
Zongxing Li ◽  
Yixuan Wang ◽  
Meihua Yang
Keyword(s):  
Source Rock ◽  
Lower Cretaceous ◽  
Inner Mongolia ◽  
Northern China ◽  
Thermal Maturity ◽  
Source Rock Evaluation

scholarly journals Evaluation of the quality, thermal maturity and distribution of potential source rocks in the Danish part of the Norwegian–Danish Basin

2008 ◽  
Vol 16 ◽  
pp. 1-66 ◽  
Author(s):  
Henrik I. Petersen ◽  
Lars H. Nielsen ◽  
Jørgen A. Bojesen-Koefoed ◽  
Anders Mathiesen ◽  
Lars Kristensen ◽  
...  
Keyword(s):  
Source Rock ◽  
Early Cretaceous ◽  
Middle Jurassic ◽  
Upper Cretaceous ◽  
Vitrinite Reflectance ◽  
Lower Jurassic ◽  
Source Rocks ◽  
Thermal Maturity ◽  
Potential Source ◽  
Petroleum Generation

The quality, thermal maturity and distribution of potential source rocks within the Palaeozoic–Mesozoic succession of the Danish part of the Norwegian-Danish Basin have been evaluated on the basis of screening data from over 4000 samples from the pre-Upper Cretaceous succession in 33 wells. The Lower Palaeozoic in the basin is overmature and the Upper Cretaceous – Cenozoic strata have no petroleum generation potential, but the Toarcian marine shales of the Lower Jurassic Fjerritslev Formation (F-III, F-IV members) and the uppermost Jurassic – lowermost Cretaceous shales of the Frederikshavn Formation may qualify as potential source rocks in parts of the basin. Neither of these potential source rocks has a basinwide distribution; the present occurrence of the Lower Jurassic shales was primarily determined by regional early Middle Jurassic uplift and erosion. The generation potential of these source rocks is highly variable. The F-III and F-IV members show significant lateral changes in generation capacity, the best-developed source rocks occurring in the basin centre. The combined F-III and F-IV members in the Haldager-1, Kvols-1 and Rønde-1 wells contain 'net source-rock' thicknesses (cumulative thickness of intervals with Hydrogen Index (HI)> 200 mg HC/g TOC) of 40 m, 83 m, and 92 m, respectively, displaying average HI values of 294, 369 and 404 mg HC/g TOC. The Mors-1 well contains 123 m of 'net source rock' with an average HI of 221 mg HC/g TOC. Parts of the Frederikshavn Formation possess a petroleum generation potential in the Hyllebjerg-1, Skagen-2, Voldum-1 and Terne-1 wells, the latter well containing a c. 160 m thick highly oil-prone interval with an average HI of 478 mg HC/g TOC and maximum HI values> 500 mg HC/g TOC.The source-rock evaluation suggests that a Mesozoic petroleum system is the most likely in the study area. Two primary plays are possible: (1) the Upper Triassic – lowermost Jurassic Gassum play, and (2) the Middle Jurassic Haldager Sand play. Potential trap structures are widely distributed in the basin, most commonly associated with the flanks of salt diapirs. The plays rely on charge from the Lower Jurassic (Toarcian) or uppermost Jurassic – lowermost Cretaceous shales. Both plays have been tested with negative results, however, and failure is typically attributed to insufficient maturation (burial depth) of the source rocks. This maturation question has been investigated by analysis of vitrinite reflectance data from the study area, corrected for post-Early Cretaceous uplift. A likely depth to the top of the oil window (vitrinite reflectance = 0.6%Ro) is c. 3050–3100 m based on regional coalification curves. The Frederikshavn Formation had not been buried to this depth prior to post-Early Cretaceous exhumation, and the potential source rocks of the formation are thermally immature in terms of hydrocarbon generation. The potential source rocks of the Fjerritslev Formation are generally immature to very early mature. Mature source rocks in the Danish part of the Norwegian–Danish Basin are thus dependent on local, deeper burial to reach the required thermal maturity for oil generation. Such potential kitchen areas with mature Fjerritslev Formation source rocks may occur in the central part of the study area (central–northern Jylland), and a few places offshore. These inferred petroleum kitchens are areally restricted, mainly associated with salt structures and local grabens (such as the Fjerritslev Trough and the Himmerland Graben).

Oil-source rock correlation studies in the unconventional Upper Cretaceous Tuscaloosa marine shale (TMS) petroleum system, Mississippi and Louisiana, USA

2020 ◽  
Vol 190 ◽  
pp. 107015 ◽  
Author(s):  
Paul C. Hackley ◽  
Kristin O. Dennen ◽  
Daniel Garza ◽  
Celeste D. Lohr ◽  
Brett J. Valentine ◽  
...  
Keyword(s):  
Source Rock ◽  
Upper Cretaceous ◽  
Petroleum System ◽  
Correlation Studies ◽  
Marine Shale ◽  
Oil Source

scholarly journals Palynofacies and Paleoenvironment investigation of the Hauterivian – Early Aptian Ratawi and Zubair formations, Balad oilfield, Central Iraq

2019 ◽  
Vol 24 (6) ◽  
pp. 74
Author(s):  
Adnan Q. Mahdi1 ◽  
Fawzi M. Al-Beyati2 ◽  
A. M. Al Tarif ◽  
El-Arabi H. Shendi4 ◽  
Mohamed I .Abdel-fattah4
Keyword(s):  
Source Rock ◽  
Marine Environment ◽  
Immature Stage ◽  
Mature Stage ◽  
Type Ii ◽  
Thermal Maturity ◽  
Observation Study ◽  
Organic Facies ◽  
Source Rock Evaluation ◽  
Oil Gas

This work depends on a detailed optical observation study of sedimentary organic facies from the Hauterivian – early Aptian Ratawi and Zubair formations from the Ba-1 well, Balad oilfield, Central Iraq. This study has manifested the advantages of palynofacies analysis methods for source rock evaluation of the studied formations, twenty five cutting rock samples organic facies data indicate a wide variation of source richness, quality and thermal maturity, the Ratawi Formation samples has the Type-II< I kerogen indicates marine environment in immature stage, while Zubair Formation has the Type-II<<  I kerogen (oil-gas prone) reflect the marine environment with  terrigenous influx in early mature to mature stage (early oil window).   http://dx.doi.org/10.25130/tjps.24.2019.111

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