Petroleum geochemical characterization of Albian-Oligocene sequences in the Campos Basin: “Case study: Eastern Marlim oilfield, offshore, Brazil”

Delgado, L.; Batezelli, Alessandro; Luna, J.

doi:10.1016/j.jsames.2018.10.009

Cited by 10 publications

(2 citation statements)

References 5 publications

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“…The A/R ‘G’ Member is early mature source rock with an average Ro% ranging from 0.62 to 0.66, and L. Kh Formation source rock lies in the early to peak stage of maturity (average Ro% ranges from 0.7 to 0.97) (Figure 9; Table 2). According to the PI versus T max diagram (Figure 10), about 50% of the studied samples are over the line of PI (0.1), which indicates a high level of conversion (Delgado et al, 2018), but the OM's hydrocarbon potential is rated as good to very good (Mansour et al, 2020) and about 50% of the studied samples are under the line of PI (0.1), which indicates a low level of conversion (Delgado et al, 2018), but the OM's hydrocarbon potential is rated as fair to good (Mansour et al, 2020). The T max values of A/R ‘A’ range from 430 to 442°C and PI values from 0.02 to 0.07 indicating an immature to mature stage.…”

Section: Resultsmentioning

confidence: 99%

Geochemical evaluation and basin modelling of the Cretaceous succession in the Azhar Oil field, West Beni Suef Basin, Egypt

Farouk,

Saada,

Fagelnour

et al. 2024

Geological Journal

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Geochemical analysis was performed on the Cretaceous sequence of the Azhar‐A‐2 well in the West Beni Suef Basin (WBSB), Western Desert, Egypt, utilizing data on total organic carbon (TOC), kerogen composition, vitrinite reflectance (Ro%) and Rock‐Eval pyrolysis. In addition, a 1D basin model was built to investigate the burial and temperature history of the study area. The most important Cretaceous source rocks are predominantly reported within the Albian Kharita Formation and Late Cenomanian‐Santonian Abu Roash (AR) Formation. Based on visual kerogen tests and Rock‐Eval pyrolysis, AR Formation (A, E, F, and G) are mixed oil‐ and gas‐prone source rocks with kerogens ranging from type II to type III, where A/R ‘A and F’ Members show dominant oil‐prone kerogen with the highest generative potential, while A/R ‘E and G’ Members are more gas‐prone kerogen. Most samples of the lower Kh Formation were interpreted as gas‐prone kerogen type III with low generative potential. On the other hand, the high amount of liptinite in the visual kerogen macerals is a strong indicator that the lower Petroleum Formation is an oil‐prone rather than gas‐prone source rock. The thermal maturity of the studied members increases consistently with depth, ranging from immature at the top of the AR Formation to the main/peak oil window at the base of the Lower Kharita Formation, which served as an active source rock for the hydrocarbons generated in the WBSB. The high value of the heat flow in the Beni Suef Basin (57 and 60 mW/m2) is a good indicator for the shallowing of the active source rock depth limit depth. From the study of the basin modeling, the main mature zone reached between 9811 and 11,090 ft in the middle of the Late Cretaceous (84.3–82.5 Ma) is through the L. Kharita Formation with three phases of hydrocarbon generation according to transformation ratio, where the second phase is the main stage in which TR is 5%–50%, showing the beginning of oil expulsion (Ro: 0.73%–0.78%, possibly 0.81%).

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Section: Resultsmentioning

confidence: 99%

Geochemical evaluation and basin modelling of the Cretaceous succession in the Azhar Oil field, West Beni Suef Basin, Egypt

Farouk,

Saada,

Fagelnour

et al. 2024

Geological Journal

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“…In addition, maximum flooding surfaces can be characterized by low sedimentation rates, and constant supply of organic-rich material under anoxic conditions that favor minimum decomposition of organic matter (Wignall, 1991;Creaney and Passey, 1993;Catuneanu et al, 2011). Additionally, an integrated approach using geochemistry and sequence stratigraphy is a reasonable way for assessing subsurface basin fills, focusing on environmental conditions (Adatte et al, 2002;Lüning et al, 2004;Slatt and Rodriguez, 2012;Daher et al, 2015;Peng et al, 2016;Omodeo-Salé et al, 2016;Delgado et al, 2018;Shekarifard et al, 2019;Adeoye et al, 2020).…”

Section: Introductionmentioning

confidence: 99%

Sequence stratigraphy and organic geochemistry: An integrated approach to understand the anoxic events and paleoenvironmental evolution of the Ceará basin, Brazilian Equatorial margin

Souza

Nascimento

Filho

et al. 2021

Marine and Petroleum Geology

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Subsurface geology and geochemical evaluation of the Middle Jurassic-Lower Cretaceous organic-rich intervals, West Kalabsha area, Western Desert, Egypt

Edress

Fagelnour²,

Hassan³

2022

Arab J Geosci

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The West Kalabsha (WKAL) area is a western extreme exploratory area of the Faghur Basin in the Western Desert of Egypt. The study of four wells (WKAL; A-1 X, K-1 X, P-1X, and C-1 X), interpreted with twenty seismic lines, shows that the area is dissected by a series of normal faults with an irregular, E–W strike direction. The general trend of the throw is toward the south–southeast. The most prospective area for hydrocarbon (HC) migration is toward the north (upthrown side) of an E-W striking normal fault north of the WKAl-K-1 X and A-1 X wells. The WKAL-P-1 X and WKAL-K-1 X wells in the Faghur Basin were selected for both geochemical evaluation of possible source rock intervals and burial history modelling within the basin. Integration of the wire-line logs with geochemical analysis identified six organic matter-rich intervals (OMRIs) within the Middle Jurassic-Lower Cretaceous sequence. Four intervals are in the Alam El-Bueib-3C (AEB-3C) member with a cumulative vertical thickness of 530ft. The other OMRIs are 110ft in thickness recorded within the AEB-6 (10ft) and Upper Safa (100ft) members. The studied organic matter (OM) reveals type III, IIIC, and IV kerogens (mainly gas-prone) with a terrestrial origin. They have reached a maturity level consistent with the late oil window. The expulsion threshold depth detected in the WKAL-P-1 X well is 12000ft in the AEB-3C member, whereas the active source depth limit (ASDL) is 15000ft in the Safa Member. The present study suggests a paleo-geothermal gradient range between 1.13oF/100ft and 1.39oF/100ft with an estimated regional erosion of 5500 to 7000ft of strata mainly between the Paleozoic-Jurassic and Cretaceous-Tertiary boundaries. The present-day geothermal gradient based on bottom-hole temperatures shows a geothermal gradient of 1.4oF/100ft (WKAL-P-1 X), that increases to the north to 1.65oF/100ft (WKAL-K-1 X). Burial history modelling reveals that sedimentary strata entered the mature oil zone in the Early Cretaceous (110–115Ma) at depths of 7500–8000ft in the deepest part of WKAL-P-1 X and WKAL-K-1 X wells (Paleozoic strata). Maturation continued to present, resulting in Jurassic and Lower Cretaceous strata currently falling into the late oil window.

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Petroleum geochemical characterization of Albian-Oligocene sequences in the Campos Basin: “Case study: Eastern Marlim oilfield, offshore, Brazil”

Cited by 10 publications

References 5 publications

Geochemical evaluation and basin modelling of the Cretaceous succession in the Azhar Oil field, West Beni Suef Basin, Egypt

Geochemical evaluation and basin modelling of the Cretaceous succession in the Azhar Oil field, West Beni Suef Basin, Egypt

Sequence stratigraphy and organic geochemistry: An integrated approach to understand the anoxic events and paleoenvironmental evolution of the Ceará basin, Brazilian Equatorial margin

Subsurface geology and geochemical evaluation of the Middle Jurassic-Lower Cretaceous organic-rich intervals, West Kalabsha area, Western Desert, Egypt

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