Past, present, and future of basin and petroleum system modeling

Baur, Friedemann; Scheirer, Allegra Hosford; Peters, Kenneth E.

doi:10.1306/08281717049

Cited by 10 publications

(6 citation statements)

References 7 publications

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“…A one‐dimensional model that benefits from a large quantity of reliable input and calibration data was created to show the consequences of the uncertainty in geothermal characteristics (related to some of the above‐mentioned pitfalls). The model was built using a frequently used commercial software package for petroleum system analysis and basin modelling (e.g., see results of a survey by Baur, Scheirer, & Peters, ). A combination of backstripping approach and forward thermal modelling was used to simulate the burial history of sediments, temperature and source rock maturation.…”

Section: Case Studymentioning

confidence: 99%

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On the importance of rock thermal conductivity and heat flow density in basin and petroleum system modelling

et al. 2019

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The role of thermal petrophysics in modelling basin and petroleum systems has been growing in recent years for at least three major reasons. First, the results of deep continental scientific drilling have led to dramatic changes in the understanding of the thermal regime at substantial depths in the interior of the Earth (Emmerman & Lauterjung, 1997; Popov, Popov, Chekhonin, Spasennykh, & Goncharov, 2019). Second, temperature is a key parameter for determining the transformation of kerogen into oil and gas, and its evaluation is impossible without reliable data on thermal properties. The most sophisticated and appropriate modelling techniques for analysing thermal histories and organic maturation levels may fail when applied to real basins if the thermal conductivity

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Section: Case Studymentioning

confidence: 99%

“…Burial history plot of the Tyumen SG‐6 well, calculated using frequently used (Baur et al, ) commercial software for basin modelling…”

Section: Case Studymentioning

confidence: 99%

On the importance of rock thermal conductivity and heat flow density in basin and petroleum system modelling

et al. 2019

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“…Multi-dimensional modeling can be particularly useful to study the generation of hydrocarbons and their migration/ accumulation histories. In addition, these techniques provide new insights about remaining exploration potential of an area by identifying new stratigraphic or unconventional plays (Alipour et al 2021;Baur et al 2017;Hantschel and Kauerauf, 2009;İnan et al 2017). The aim of this study was to gain a deeper insight about the evolution of the Cretaceous petroleum system in the eastern Persian Gulf basin.…”

Section: Introductionmentioning

confidence: 99%

Basin and petroleum system analysis in the southeastern Persian Gulf basin: a 2D basin modeling approach

Alipour

Alizadeh

Mirzaie³

et al. 2021

J Petrol Explor Prod Technol

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A regional 2D conceptual model was constructed to study the hydrocarbon systems associated with the Middle Sarvak source rock (Cenomanian) in the southeastern Persian Gulf basin. The 2D cross section used for this purpose was 135 km long and encompassed a total of 17 depositional units with the Late Jurassic Surmeh Formation at the base and the Aghajari/Mishan sequences at the top. Compositional type II-S kinetics was considered for the Middle Sarvak source rock, and the model predictions were calibrated against observe data (corrected bottom hole temperatures and vitrinite reflectance data) coming from 4 wells located on the studied cross section. Our results indicate that hydrocarbons predominantly migrate laterally from east to the west of the study area, thereby sequentially charging potential traps en-route. The interaction between facies patterns and geodynamic evolution controls both the distribution and quality of hydrocarbon accumulations in the study area. The calibrated 2D model reliably predicts most of the present-day hydrocarbon occurrences in the study area and explains the present-day variations in their bulk properties. Our findings provide new insights about the unconventional plays associate with the Middle Sarvak source rock especially in the central parts of the southeastern Persian Gulf basin.

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“…The deviation between the modelling and field data is attributed to the effects of the Earth thermal gradient [21][22][23]. Mathematical models for secondary migration of single-phase multicomponent oil-gas fluids reflect numerous processes of mass transfer between the rock and fluid occurring during secondary migration of hydrocarbons [2][3][4][5][6][7][8][9]. Regarding flow simulation during secondary petroleum migration, the models includes non-equilibrium adsorption and its hysteresis, diffusion and dispersion, and advective transport with Darcy's velocity [10][11][12][13][14].…”

Section: Introductionmentioning

confidence: 99%

“…Extensions of the thermo-gravitational equilibrium conditions for two-and three-phase multicomponent fluids with adsorption and chemical reactions are presented in works [21][22][23]27,28]. Being implemented into software Themis, the mathematical models for secondary migration predict compositional gradients of petroleum fluids due to losing their heavy components by adsorption during secondary migration [5][6][7][8][9].…”

Section: Introductionmentioning

confidence: 99%

Composition Changes of Hydrocarbons during Secondary Petroleum Migration (Case Study in Cooper Basin, Australia)

et al. 2019

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The reliable mathematical modelling of secondary petroleum migration that incorporates structural geology and mature source rocks in the basin model, allows for prediction of the reservoir location, yielding the significant enhancement of the probability of exploration success. We investigate secondary petroleum migration with a significant composition difference between the source and oil pools. In our case study, the secondary migration period is significantly shorter than the time of the hydrocarbon pulse generation. Therefore, neither adsorption nor dispersion of components can explain the concentration difference between the source rock and the reservoir. For the first time, the present paper proposes deep bed filtration of hydrocarbons with component kinetics retention by the rock as a physics mechanism explaining compositional grading. Introduction of the component capture rate into mass balance transport equation facilitates matching the concentration difference for heavy hydrocarbons, and the tuned filtration coefficients vary in their common range. The obtained values of filtration coefficients monotonically increase with molecular weight and consequently affects the size of the oleic component, as predicted by the analytical model of deep bed filtration. The modelling shows a negligible effect of component dispersion on the compositional grading.

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Past, present, and future of basin and petroleum system modeling

Cited by 10 publications

References 7 publications

On the importance of rock thermal conductivity and heat flow density in basin and petroleum system modelling

On the importance of rock thermal conductivity and heat flow density in basin and petroleum system modelling

Basin and petroleum system analysis in the southeastern Persian Gulf basin: a 2D basin modeling approach

Composition Changes of Hydrocarbons during Secondary Petroleum Migration (Case Study in Cooper Basin, Australia)

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