Seismic Petrophysics in Quantitative Interpretation

Vernik, Lev

doi:10.1190/1.9781560803256

Cited by 143 publications

(79 citation statements)

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“…We consider data from six wells in the Ling Depression and Egersund Basin, in locations where maturation is limited (Table 2; Ritter, 1988), to investigate the effect of TOC on the elastic properties. We also employ a kerogen substitution method to complement our interpretations and support the proposed trends (Vernik, 2016). A limitation for using the model is that we necessarily have to generalize mineralogical fractions (Kalani et al, 2015b), and estimate non-kerogen and kerogen properties using standard values, since which we currently lack explicit measurements.…”

Section: Establishing Trends Using Multiple Seismic Propertiesmentioning

confidence: 95%

“…Due to distances between the wells being studied, additional factors such as compositional and depositional differences can influence the elastic signatures and potentially obscure the independent effect of TOC. Kerogen substitution is applied to the Tau Formation shale in well 17/12-4, to predict elastic properties at different TOC levels (Vernik, 2016). We assume kerogen density ρ k = 1.13 g/cm 3 based on R o ≈ 0.5% (Equation 2).…”

Section: Toc Effect In Shales At Intermediate Maximum Burial Depth (2mentioning

confidence: 99%

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Organic content and maturation effects on elastic properties of source rock shales in the Central North Sea

2019

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We have investigated the effects of organic content and maturation on the elastic properties of source rock shales, mainly through integration of a well-log database from the Central North Sea and associated geochemical data. Our aim is to improve the understanding of how seismic properties change in source rock shales due to geologic variations and how these might manifest on seismic data in deeper, undrilled parts of basins in the area. The Tau and Draupne Formations (Kimmeridge shale equivalents) in immature to early mature stages exhibit variation mainly related to compaction and total organic carbon (TOC) content. We assess the link between depth, acoustic impedance (AI), and TOC in this setting, and we express it as an empirical relation for TOC prediction. In addition, where S-wave information is available, we combine two seismic properties and infer rock-physics trends for semiquantitative prediction of TOC from [Formula: see text] and AI. Furthermore, data from one reference well penetrating mature source rock in the southern Viking Graben indicate that a notable hydrocarbon effect can be observed as an addition to the inherently low kerogen-related velocity and density. Published Kimmeridge shale ultrasonic measurements from 3.85 to 4.02 km depth closely coincide with well-log measurements in the mature shale, indicating that upscaled log data are reasonably capturing variations in the actual rock properties. Amplitude variation with offset inversion attributes should in theory be interpreted successively in terms of compaction, TOC, and maturation with associated generation of hydrocarbons. Our compaction-consistent decomposition of these effects can be of aid in such interpretations.

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Section: Establishing Trends Using Multiple Seismic Propertiesmentioning

confidence: 95%

Section: Toc Effect In Shales At Intermediate Maximum Burial Depth (2mentioning

confidence: 99%

Organic content and maturation effects on elastic properties of source rock shales in the Central North Sea

2019

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“…There are a number of experimental compaction laws available that relate porosity loss to an increase in effective stress (for example see Vernik ). These relations are lithology specific, and hence we can be more accurate if we identify relationships relevant to local geology.…”

Section: Methodsmentioning

confidence: 99%

A rock physics model to map gross lithology using compaction

Gallop

Babak

Liu

2019

Geophysical Prospecting

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Differential compaction has long been used by seismic interpreters to infer subsurface geology using knowledge of the relative compaction of different types of sediments. We outline a method to infer the gross fraction of shale in an interval between two seismic horizons using sandstone and shale compaction laws. A key component of the method involves reconstruction of a smooth depositional horizon by interpolating decompacted thicknesses from well control. We derive analytic formulae for decompaction calculations using known porosity–stress relations and do not employ discrete layer iterative methods; these formulae were found to depend not only upon the gross fraction of shale but also on the clay content of the shales and the thickness of the interval. The relative merits of several interpolation options were explored, and found to depend upon the structural setting. The method was successfully applied to an oil sands project in Alberta, Canada.

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“…Существует ряд факторов, влияющих на точность определения модуля C 13 и, следовательно, параметра δ по измерениям скоростей ультразвуковых волн в образцах, например: (Sarout et al, 2015;Vernik, 2016;Yan et al, 2016). Точность оценки параметра C 13 зависит от точности измерений фазовой скорости продольной (Р) волныV p , распространяющейся в интервале углов между 0 и 90° (чаще всего измеряетсяVp 45 при φ = 45°).…”

Section: Introductionunclassified