Rock Physics Relationships between Compressional, Shear, and Density Logs in Unconventional Formations, Including Deviated Wells
Date: Wednesday, 13 January, 2016
Location: Repsol, 2455 Technology Forest Blvd The Woodlands, TX 77381
Lunch is served at 11, talk/discussion 11.30-12.30
Regular $25, Student $10 (Lunch included)
Title: Rock Physics Relationships between Compressional, Shear, and Density Logs in Unconventional Formations, Including Deviated Wells
This presentation compares rock physics trends in the Vp-vs.-Vs crossplot and the Vp/Vs-vs.-compressional slowness crossplot. Trend uncertainties are presented with laboratory data from the Bakken, Bazhenov, Monterey, and Niobrara shales; departures from expected trends attributed to kerogen, hydrocarbon, anisotropy, and well deviation are discussed. Anisotropy models, such as ANNIE (Schoenberg et al.1996), are presented for computing Thomsen parameters and stiffness coefficients.
Castagna mudrock line (Castagna et al. 1993) derived from in-situ sonic and seismic measurements provided an average linear relationship between compressional and shear-wave velocities. Brie (1995) extended previous work to include predicting gas saturation from a Vp/Vs-vs.-compressional slowness crossplot. Projecting the Castagna mudrock line onto a shear-vs.-compressional slowness crossplot proved useful for interpreting sonic data. Classical-rock physics equations were used to model compressional and shear velocities as a function of well deviation. Laboratory anisotropy models allowed for characterizing the effects of dispersion, anisotropy, and well deviation.
Anisotropic-rock physics models for the Bakken, Bazhenov, Monterey, and Niobrara organic shales are presented and compared in terms of the Thomsen parameters, e, g, and d, and stiffness coefficients, Cij. These models are first transposed to trend curves in Vp-vs.-Vs, Vp/Vs-vs.-compressional slowness, and shear-vs.-compressional slowness crossplots and then compared to the Castagna mudrock trend curve. The anisotropy models are then applied to characterize the effect of well deviation on these trend curves. Results are also presented for well log data from the Eagle Ford, Haynesville, and Bakken formations in the context of the discussed crossplots and then compared with the expected trend curves. The Eagle Ford data satisfies the carbonate Vp-vs.-Vs trend predicted in previous literature by Castagna et al. (1993), and the Haynesville data clearly satisfies the gas effect predicted by the Brie Vp/Vs-vs.-compressional slowness crossplot discussed.
In theory, the models describing anisotropy with the Thomsen parameters or stiffness coefficients are equivalent. In practice, not all the parameters for either model can be measured from log data. Preferentially, anisotropic models should be derived by combining log data from multiple vertical, deviated, and horizontal wells for each shale reservoir.
John Quirein is a Halliburton Technology Fellow and petrophysicist supporting the Integrated Interpretation Group, focusing on integrated interpretation and software development with a recent emphasis on gas shale petrophysics, geochemical log interpretation, geomechanics, and multi-mineral solvers. Quirein received a PhD from the University of Houston, and then worked 10 years for Schlumberger, 12 years for Mobil, and the past 16 years for Halliburton. He is a past SPWLA president and past SPWLA Foundation president.