Evolution of temperature, maturation level and realization of hydrocarbon potential in subtrappean sedimentary complex of the Bombay offshore – Results of 1-D basin modeling

Galushkin, Yu. I.

doi:10.1016/j.marpetgeo.2015.07.005

Cited by 4 publications

(1 citation statement)

References 30 publications

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“…11b). In summary, the Late Cretaceous sediments are generally characterised by relatively Gombos et al 1995;Galushkin 2015;Varma et al 2015;Premarathne et al 2016). However, the increment of Tmax values falls within a narrow range during the Cretaceous (Fig.…”

Section: Thermal Maturity and Hydrocarbon Generation Potentialmentioning

confidence: 85%

Assessment of hydrocarbon generation potential and thermal maturity of the offshore Mannar Basin, Sri Lanka

Ratnayake

Kularathne²,

Sampei

2017

J Petrol Explor Prod Technol

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The Mannar Basin is an under-explored offshore sedimentary basin in terms of petroleum geology. The Cretaceous to Paleogene cutting samples were collected in three offshore exploration wells (i.e. the Dorado North, Dorado and Barracuda) in the Mannar Basin. In this study, kerogen type, quantity and thermal maturity of sedimentary organic matter were ascertained using Rock-Eval pyrolysis and vitrinite reflectance analyses. In addition, 1-D basin modelling was used to analyse the timing of hydrocarbon generation in the Mannar Basin. Total organic carbon (TOC) contents and total hydrocarbon potential are higher in the Cretaceous calcareous mudstones than in the Paleogene calcareous silty/sandy mudstones. TOC contents show a negative correlation with oxygen index. Hydrogen index and oxygen index values range from 77 to 785 mg HC/g TOC and from 25 to 165 mg HC/g TOC, respectively. Organic matters were identified as mixed Type II-III and Type III kerogen. Maturity expressed in term of Tmax and vitrinite reflectance range from 332 to 456 °C and from 0.26 to 1.49%, respectively. It indicates both immature and mature sediments. In general, maturity values are relatively high in the Late Cretaceous sediments (Tmax, from 332 to 456 °C, average = 423 °C ± 25) compared to the Paleogene sediments (Tmax, from 388 to 431 °C, average 419 °C ± 10). Geochemical proxies show that oil and gas prone (Type II-III) and gas prone (Type III) kerogen-rich Late Cretaceous sediments of the Dorado and Barracuda wells have principally achieved maturity levels for oil window. Therefore, it suggests incomplete thermal conversion for the wet gas generation in the northeast part of the Mannar Basin. In the 1-D basin modelling, the maximum hydrocarbon generation was observed during the Neogene Period in the Late Cretaceous sediments of the deeper Barracuda well.

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Section: Thermal Maturity and Hydrocarbon Generation Potentialmentioning

confidence: 85%