Preface 1. Basic tools 2. Elasticity and Hooke's law 3. Seismic wave propagation 4. Effective media 5. Granular media 6. Fluid effects on wave propagation 7. Empirical relations 8. Flow and diffusion 9. Electrical properties Appendices.

/pdf/the-rock-physics-handbook-tools-for-seismic-analysis-of-58lw74s1oi.pdf

The Rock Physics Handbook: Tools for Seismic Analysis of Porous Media

Shale-gas resource plays can be distinguished by gas type and system characteristics. The Newark East gas field, located in the Fort Worth Basin, Texas, is defined by thermogenic gas production from low-porosity and low-permeability Barnett Shale. The Barnett Shale gas system, a self-contained source-reservoir system, has generated large amounts of gas in the key productive areas because of various characteristics and processes, including (1) excellent original organic richness and generation potential; (2) primary and secondary cracking of kerogen and retained oil, respectively; (3) retention of oil for cracking to gas by adsorption; (4) porosity resulting from organic matter decomposition; and (5) brittle mineralogical composition. The calculated total gas in place (GIP) based on estimated ultimate recovery that is based on production profiles and operator estimates is about 204 bcf/section (5.78 × 10 9 m 3 /1.73 × 10 4 m 3 ). We estimate that the Barnett Shale has a total generation potential of about 609 bbl of oil equivalent/ac-ft or the equivalent of 3657 mcf/ac-ft (84.0 m 3 /m 3 ). Assuming a thickness of 350 ft (107 m) and only sufficient hydrogen for partial cracking of retained oil to gas, a total generation potential of 820 bcf/section is estimated. Of this potential, approximately 60% was expelled, and the balance was retained for secondary cracking of oil to gas, if sufficient thermal maturity was reached. Gas storage capacity of the Barnett Shale at typical reservoir pressure, volume, and temperature conditions and 6% porosity shows a maximum storage capacity of 540 mcf/ac-ft or 159 scf/ton.

/pdf/unconventional-shale-gas-systems-the-mississippian-barnett-2w1ilks6bo.pdf

Unconventional shale-gas systems: The Mississippian Barnett Shale of north-central Texas as one model for thermogenic shale-gas assessment

Responding to the latest developments in rock physics research, this popular reference book has been thoroughly updated while retaining its comprehensive coverage of the fundamental theory, concepts, and laboratory results. It brings together the vast literature from the field to address the relationships between geophysical observations and the underlying physical properties of Earth materials - including water, hydrocarbons, gases, minerals, rocks, ice, magma and methane hydrates. This third edition includes expanded coverage of topics such as effective medium models, viscoelasticity, attenuation, anisotropy, electrical-elastic cross relations, and highlights applications in unconventional reservoirs. Appendices have been enhanced with new materials and properties, while worked examples (supplemented by online datasets and MATLAB® codes) enable readers to implement the workflows and models in practice. This significantly revised edition will continue to be the go-to reference for students and researchers interested in rock physics, near-surface geophysics, seismology, and professionals in the oil and gas industries.

The Rock Physics Handbook

Natural gas origin, composition, and processing: A review

Geochemical evolution of organic-rich shales with increasing maturity: A STXM and TEM study of the Posidonia Shale (Lower Toarcian, northern Germany)

Natural and artificial maturation of biological markers in a Toarcian shale from northern Germany

The universality of the relationship between vitrinite reflectance and transformation ratio

Paleozoic sedimentary rocks fill the Michigan Basin and provide the sources of the oils produced from this basin. The present geothermal gradient is not high in this shallow sequence, raising questions as to whether Devonian and younger strata are sufficiently thermally mature to have sourced petroleum. The thermal maturities of rock samples from Late Cambrian to Pennsylvanian strata have been determined using the kinetics of apparent transformations of biomarker molecules as an index, augmented by vitrinite reflectance measurements and Rock-Eval pyrolysis data. From the extents of sterane isomerization and the degrees of steroid aromatization in biomarkers extracted from these samples, the geothermal history of the Michigan Basin has been reconstructed. Organic matter in Devonian strata from the center of the basin is thermally mature; it is overmature in Ordovician rocks. The geological history of this basin has evidently been more complex than generally thought, suggesting higher temperatures or lower conduction rates in the past.

Biological Markers in Paleozoic Sedimentary Rocks and Crude Oils from the Michigan Basin: Reassessment of Sources and Thermal History of Organic Matter

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Natural and artificial maturation of biological markers in a Toarcian shale from northern Germany

The universality of the relationship between vitrinite reflectance and transformation ratio

Biological Markers in Paleozoic Sedimentary Rocks and Crude Oils from the Michigan Basin: Reassessment of Sources and Thermal History of Organic Matter