Abstract
The accumulation of organic matter is the basis for gas generation and significantly affects the ultimate gas production in shale reservoirs. Estimation of organic enrichment using seismic data is essential for shale gas characterization. The commonly used correlations between elastic properties and organic matter content for a particular area are locally applicable but may not be workable for other zones. Herein, a general physics-based approach is proposed to predict organic enrichment in shales. An organic matter-matrix decoupling amplitude variation versus offset (AVO) formula is constructed to straightforwardly quantify seismic signatures of organic matter via an introduced organic matter-related factor (Mc). Then, the elastic impedance (EI) function is established from the decoupling AVO formula to compute Mc. The proposed EI inversion method is suitable for capturing organic enrichment, particularly in the case of inadequate petrophysics information for reliable evaluation of Mc using log data as a constraint in the inversion. The developed AVO formula and EI function regard the organic matter as solid pore-fillings, presenting a more reasonable model for organic shales. Numerical tests show that Mc exhibits enhanced sensitivity to organic matter content with respect to the regularly used elastic properties. The real data applications indicate that the estimated Mc agrees well with the gas production in horizontal development wells, suggesting that Mc is a good indicator of favorable gas areas. The proposed approach may have broader potential applications and can be extended to detect other fluids and solid-saturated hydrocarbon reservoirs such as shale oil, heavy oil, and gas hydrates.
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Acknowledgments
This work was supported by the National Natural Science Foundation of China (Grant No. 42074153 and 42274160). The authors thank the Editor in Chief Prof. Michael J. Rycroft and two anonymous reviewers for their constructive comments and suggestions.
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Conceptualization was contributed by ZG; methodology was contributed by ZG, XL; formal analysis was contributed by ZG, XL; investigation was contributed by ZG, XL; writing—review and editing, was contributed by ZG; validation was contributed by ZG; Software was contributed by XL; Visualization was contributed ZG, XL; writing—original draft, was contributed by ZG, XL; supervision was contributed by CL; resources were contributed by ZG, CL; data curation was contributed by XL.
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Appendices
Appendix 1
Establishment of the Organic Matter–Matrix Decoupling AVO Formula
According to Russell et al. (2011), P- and S-wave velocities, VP and VS, can be expressed using Eqs. (1) and (2) as:
where ρ is the bulk density of shale.
Then, the two organic matter-related parameters in Eqs. (1) and (2) have the following forms:
where γdry represents the dry frame’s VP/VS ratio.
Aki and Richards (2002) proposed a linearized approximation of the PP-wave reflectivity as follows:
where θ is the average of the incidence and refraction angles; \(\overline{V}_{{\text{P}}}\), \(\overline{V}_{{\text{S}}}\), and \(\overline{\rho }\) are the averaged velocities and bulk density across the boundary, and the bar “–” will be omitted in the following expressions for simplicity; ∆ denotes the difference in according parameters across the interface; γsat represents the averaged VP/VS ratio of rocks.
Based on Russell et al. (2011), Eq. (20) can be rearranged as the following forms:
where the expression γsat = VP/VS is considered.
Treating γdry as a constant and applying the chain rule of the multivariable calculus to Eqs. (18) and (19) give:
Substituting Eqs. (18) and (19) into Eqs. (22) and (23) produces:
Equations (24) and (25) can be further rearranged as follows:
Substituting Eqs. (26) and (27) into Eq. (21), we have:
Using µdry = µsat –Mµ according to Eq. (19) and setting µ = µsat by neglecting the subscript “sat” for simplicity, we further rearrange Eq. (28)as:
Dividing Eqs. (18) and (19) by ρVP2 on both sides gives:
Substituting Eq. (31) into Eq. (30) produces:
Equation (32) can be expressed considering µdry = µsat–Mµ = ρVs2 – Mµ:
Equation (33) can be further rearranged as follows:
Substituting Eq. (34) into Eq. (29) produces:
Equation (35) is further rearranged using ρVP2 = γsat2ρVS2 = γsat2μ:
Introducing the factor N = Mμ/Mk can rearrange Eq. (36) to give the ultimate form of the organic matter-matrix decoupling formula:
For fluid saturation, we have Mµ = 0 due to µdry = µsat in Eq. (19). Therefore, the factor N = Mμ/Mk = 0 in this case, making Eq. (37) expressed as:
Equation (38) has the same form of the formula proposed by Russell et al. (2011), with the term ΔMk /Mk equivalent to the fluid term Δf /f in their paper.
Appendix 2
EI Inversion Based on the Organic Matter-Matrix Decoupling AVO Formula
According to the theory of Connolly (1999), the PP-wave reflection coefficient is expressed by EI:
Substituting Eq. (39) into Eq. (7) gives:
Using the relationship \(\frac{\Delta x}{x} \approx \Delta \ln x\) produces:
By denoting the weighting coefficients in Eq. (41) as follows:
Equation (42) can be simplified in the following form:
The EI-based formula is obtained by integrating and exponentiating both sides of Eq. (43):
According to Whitcombe et al. (2002), Eq. (44) should be properly scaled for directly comparing EI values at different incidence angles:
where Mc0, µ0, and ρ0 represent the averaged values of Mc, µ, and ρ calculated from log data for the target depth interval. The normalization factor A corresponds to EI(0°) in Eq. (44), which has the expression:
Taking the log function on both sides of Eq. (45) gives:
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Guo, Z., Lv, X. & Liu, C. Estimating Organic Enrichment in Shale Gas Reservoirs Using Elastic Impedance Inversion Based on an Organic Matter−Matrix Decoupling Method. Surv Geophys 44, 1985–2009 (2023). https://doi.org/10.1007/s10712-023-09789-6
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DOI: https://doi.org/10.1007/s10712-023-09789-6