An Effective Reservoir Parameter for Seismic Characterization of Organic Shale Reservoir

Zhao, Luanxiao; Qin, Xuan; Liu, Xiwu; Han, De‐hua; Geng, Jianhua; Xiong, Yongjiao

doi:10.1007/s10712-017-9456-9

Cited by 41 publications

(12 citation statements)

References 49 publications

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“…Vernik and Liu ; Zhao et al . ), thus

Δ C_{11 - 33} \geq 0

. Based on this logic and recalling that C 12 must be positive, we can constrain the range of C 11 and C 12 using the values of

C_{11} + C_{12}

and C 33 :

C_{12, \max} = C_{11} + C_{12} - C_{33},

C_{12, \min} = 0,

C_{11, \max} = C_{11} + C_{12},

C_{11, \min} = C_{33} .

Moreover, since

C_{66} = \frac{C_{11} - C_{12}}{2}

, then

C_{66, \max} = \frac{C_{11, \max} - C_{12, \min}}{2},

C_{66, \min} = max \{\frac{C_{11, \min} - C_{12, \max}}{2}, 0\} .

…”

Section: Methodsmentioning

confidence: 99%

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Static and dynamic elastic moduli of organic‐rich chalk

Shitrit

Hatzor

Feinstein

et al. 2019

Geophysical Prospecting

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The elastic moduli and anisotropy of organic‐rich rocks are of great importance to geoengineering and geoprospecting of oil and gas reservoirs. In this paper, we probe into the static and dynamic moduli of the Ghareb–Mishash chalk through laboratory measurements and new analytical approaches. We define a new anisotropy parameter, ‘hydrostatic strain ratio’ (Ω), which describes the differential contraction of anisotropic rocks consequent to hydrostatic compression. Ω depends on the C11, C12, C13 and C33 stiffness constants of a transversely isotropic material, and therefore enables a unique insight into the anisotropic behaviour of TI rocks. Ω proves more sensitive to anisotropy within the weak anisotropy range, when compared with Thomsen's ε and γ parameters. We use Ω to derive static moduli from triaxial compression tests performed on a single specimen. This is done by novel employment of a hydrostatic‐deviatoric combination for transversely isotropic elastic stiffnesses. Dynamic moduli are obtained from acoustic velocities measurements. We find that the bedding‐normal velocities are described well by defining kerogen as the load‐supporting matrix in a Hashin–Shtrikman model (‘Hashin–Shtrikman (HS) kerogen’). The dynamic moduli of the Ghareb–Mishash chalk in dry conditions are significantly higher than the static moduli. The dynamic/static moduli ratio decreases from ∼4 to ∼2 with increasing kerogen content. Both the static and dynamic moduli decrease significantly with increasing porosity and kerogen content. The effect of porosity on them is two times stronger than the effect of kerogen.

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“…Vernik and Liu ; Zhao et al . ), thus

Δ C_{11 - 33} \geq 0

. Based on this logic and recalling that C 12 must be positive, we can constrain the range of C 11 and C 12 using the values of

C_{11} + C_{12}

and C 33 :

C_{12, \max} = C_{11} + C_{12} - C_{33},

C_{12, \min} = 0,

C_{11, \max} = C_{11} + C_{12},

C_{11, \min} = C_{33} .

Moreover, since

C_{66} = \frac{C_{11} - C_{12}}{2}

, then

C_{66, \max} = \frac{C_{11, \max} - C_{12, \min}}{2},

C_{66, \min} = max \{\frac{C_{11, \min} - C_{12, \max}}{2}, 0\} .

…”

Section: Methodsmentioning

confidence: 99%

“…In a typical VTI material, negative Thomsen's ε values are very uncommon (e.g. Vernik and Liu 1997;Zhao et al 2017), thus C 11−33 ≥ 0. Based on this logic and recalling that C 12 must be positive, we can constrain the range of C 11 and C 12 using the values of C 11 + C 12 and C 33 :…”

Section: Elastic Moduli Derivation From Triaxial Testsmentioning

confidence: 99%

Static and dynamic elastic moduli of organic‐rich chalk

Shitrit

Hatzor

Feinstein

et al. 2019

Geophysical Prospecting

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“…Recently by application of horizontal drilling along with multistage hydraulic fracturing have expand the ability to get production from these low permeability self-resource reservoirs. Now unconventional resources have become an important source of energy worldwide 1 . The successful production of these self-resourcing rocks largely depended on amount of organic matter (OM) a soft component and shale brittleness a hard component.…”

mentioning

confidence: 99%

“…Per Avseth and Carcione 13 developed rock physics models for screening organic richness. Zhao et al 1 use sum of organic matter and porosity is to delineate organic shale to identify reservoir parameters. Del Monte et al 14 used seismic inversion and rock physics modeling to estimate organic matter on seismic data.…”

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confidence: 99%

Effective Attributes Quantification to Bridge Gap between Elastic Properties and Reservoir Parameters in Self-Resource Rocks

Abid

Geng

2020

Sci Rep

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The successful production of unconventional resources such as shale gas is highly dependent on its two reservoir properties, organic matter and rock brittleness. High resolution spatially characterization of these two unconventional reservoir properties needs surface reflection seismic data. However, to delineate these two parameters on seismic scale is a challenging task because poor correlation is observed between these parameters and elastic properties of the rock. To encounter this adversity in current study we proposed effective attributes method in which organic shale reservoir properties are divided into their hard and soft elastic response. From the analysis of worldwide laboratory dataset, we find that hard and soft components have shown us much better linear correlation with P-and S-wave impedance. The proposed effective attributes, helped us to reduce the gap between unconventional reservoir properties and seismic characteristics. These attributes are the main controlling factor for rock elastic properties and exhibit information about hydrocarbon generation capacity and rock brittleness. A well data example from Sembar shale has also shown successful results for proposed effective attributes methodology. These attributes application on inverted P-wave impedance seismic data of employed organic shale reservoir have shown productive results to quantify its unconventional prospect on seismic scale. The approach used in this study can be confidently employed to assess unconventional reservoir potential in other parts of the world.

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“…In recent years, research on characterization of source rock shales has become more frequent due to the value of exploiting unconventional shale reservoirs (e.g., Passey et al, 1990;Vernik and Landis, 1996;Passey et al, 2010;Vernik and Milovac, 2011;Alfred and Vernik, 2012;Zhu et al, 2012;Sayers, 2013a;Yenugu and Vernik, 2015;Zhao et al, 2018). However, the understanding and theories developed are in principle equally applicable for characterization of organic-rich shales as conventional hydrocarbon source rocks.…”

mentioning

confidence: 99%

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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An Effective Reservoir Parameter for Seismic Characterization of Organic Shale Reservoir

Cited by 41 publications

References 49 publications

Static and dynamic elastic moduli of organic‐rich chalk

Static and dynamic elastic moduli of organic‐rich chalk

Effective Attributes Quantification to Bridge Gap between Elastic Properties and Reservoir Parameters in Self-Resource Rocks

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

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