Source rock evaluation in the central-western flank of the Tampico Misantla Basin, Mexico

Vega-Ortiz, Carlos; Beti, Dhrupad R.; Setoyama, Eiichi; McLennan, John; Ring, Terry A.; Levey, Raymond A.; Martínez-Romero, Néstor

doi:10.1016/j.jsames.2020.102552

Cited by 13 publications

(3 citation statements)

References 19 publications

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“…The Fahdene Formation source rock is dominated by clayey marls as inferred by the equal contents of steranes and diasteranes in the extracts analysed, and in addition by an abundance of C 30 hopanes compared to C 29 hopanes. For the Bahloul Formation, source rock extracts contain a slight dominance of diasteranes compared to steranes and higher values of the C 30 / C 29 hopanes ratio, indicating a more clay-dominated lithology (Clark and Philp, 1989;Sinninghe Damsté et al, 1993;Hakimi and Al-Sufi, 2018;Vega-Ortiz et al, 2020).…”

Section: Source Rock Characterizationmentioning

confidence: 99%

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Kort

Elmola

Ouazaa

et al. 2021

Journal of Petroleum Geology

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An increase in source rock thermal maturity is in general linked to burial‐related heating according to the regional geothermal gradient, but maturities may also locally be influenced by high‐temperature hydrothermal fluids or igneous intrusions. In the present study of the Isis field located in the Gulf of Gabes (offshore Tunisia), we combine an analysis of organic matter maturity indicators and clay mineral signatures to constrain possible fluid/rock interactions and to define controls on the maturity of potential source rocks. Cuttings samples were collected from source rock intervals in the Cretaceous Bahloul (Cenomanian – Turonian) and underlying Fahdene (Albian – Cenomanian) Formations at the PM borehole, and detailed organic geochemical and clay mineralogical analyses of source rock samples and extracts were carried out. Samples from the Bahloul Formation (2381 m to 2400 m) consist of black to dark grey claystones and globigerinid limestones. Those from the Fahdene Formation (2400 m to 2700 m) comprise alternating claystones and chalky limestones containing globigerinids including Ticinella primula. Both source rock intervals have similar mineralogical compositions consisting of calcite, quartz, albite, anorthite, minor anatase, pyroxene and pyrite. The clay mineralogy of the formations is composed of abundant smectite (two generations), subordinate kaolinite and minor illite and/or mica. The Fahdene source rock contains organic matter consisting of mixed kerogen Types II/III; Type II OM is present in the Bahloul Formation.At the borehole location, the source rock intervals in the Fahdene and Bahloul Formations have been affected by hydrothermal fluids which are derived from an unconformably overlying basalt succession which is >300 m thick. Based on bulk mineral assemblages, the Bahloul Formation has been modified by the hydrothermal fluids more significantly than the underlying Fahdene Formation. Analyses of the clay minerals compositions indicate that interactions between the hydrothermal fluids and the host rocks were very rapid and were localized within fractures and micropores. The Bahloul Formation source rocks have reached an advanced stage of thermal maturity (overmature or end‐ oil window) compared to the thermally immature source rocks in the Fahdene Formation.The results show that the main control on source rock maturation at the studied well was maximum palaeotemperature and this may locally have been influenced by short‐term hydrothermal and magmatic heating as well as by the regional geotherm. Clay minerals were less affected by hydrothermal heating compared to organic matter indices; this may be because mineral components are slower to react to short‐term higher temperature conditions than organic matter.Thus magmatic activity and hydrothermal fluids may locally accelerate the thermal maturation of source rocks even at shallow depths. The study also shows that a combination of clay mineral characterization and organic matter indicators can be useful for the assessment of thermal maturity in potential source rocks.

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Section: Source Rock Characterizationmentioning

confidence: 99%

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Kort

Elmola

Ouazaa

et al. 2021

Journal of Petroleum Geology

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“…Macroscopically, it is also necessary to evaluate the thicknesses distribution of source rocks. 8 − 10 …”

Section: Introductionmentioning

confidence: 99%

“…Therefore, the characteristics and evaluation of source rocks have become the top priority of oil and gas exploration. , The geochemical characteristics of source rocks mainly focus on the abundance, type, and maturity of organic matters. Macroscopically, it is also necessary to evaluate the thicknesses distribution of source rocks. − …”

Section: Introductionmentioning

confidence: 99%

Geochemical Characteristics and Distribution of the Subsalt Source Rocks in the Santos Basin, Brazil

Zuo¹,

Wang²,

Fan³

et al. 2022

ACS Omega

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The Santos Basin in Brazil is a hot area of oil and gas exploration in recent years, and its subsalt lacustrine mudstones are the main source rock of the basin. However, there is a lack of studies on the source rocks of the subsalt Picarras and Itapema formations, which is not conducive to the accurate evaluation of the source rock characteristics. Based on logging data of 51 wells and geochemical data of 16 wells, this paper makes detailed evaluations of the organic matter abundance, type, maturity, and distribution characteristics of source rocks of the subsalt Picarras Formation and Itapema Formation in the Santos Basin. The results show that the characteristics of source rocks of the Itapema and Picarras formations are similar, both of which have a high abundance of organic matter. The types of organic matter are mainly type I and II 1 , and the maturities are in the low-maturity to the high-maturity stage, which meets the standard of good source rocks. The total organic carbon content of the source rocks of the Picarras Formation ranges from 0.4 to 4.0%, much lower than that of the source rocks of the Itapema Formation, 0.8–5.6%. In addition, the hydrogen index average value of the source rocks of the Itapema Formation is 712.8 mg/g TOC, higher than that of the Picarras Formation, 697.5 mg/g TOC, both revealing a great hydrocarbon potential. The quality of source rocks of the Itapema Formation is better than that of the Picarras Formation. The two sets of source rocks have great hydrocarbon generation potential and are mainly developed in the eastern and western sags of the central depression. Therefore, the surrounding uplift areas will be the target for further oil and gas exploration.

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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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Source rock evaluation in the central-western flank of the Tampico Misantla Basin, Mexico

Cited by 13 publications

References 19 publications

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Maturity of Potential Cretaceous Source Rocks at the Isis Field, Offshore Eastern Tunisia: Influence of Hydrothermal Fluids

Geochemical Characteristics and Distribution of the Subsalt Source Rocks in the Santos Basin, Brazil

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

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