Rocks characteristics

Foley SF, Venturelli G, Green DH, Toscani L (1987) The ultrapotassic rocks characteristics classification, and constraints for petrogenetic models. Earth Sci Rev 24 81-134... 

CarroU, R. R, Pashin, J. C., and Kugler, R. L, 1995, Burial history and source-rock characteristics of Upper Devonian through Pennsylvanian strata. Black Warrior basin, Alabama Geological Survey of Alabama Circular, v. 187, p. 29. 

Effect of Rock Characteristics. Rock characteristics that affect mechanically induced fines migration include the following absolute permeability, pore geometry and pore size distribution, size distribution of fines, amount and type of fines present in the rock, and the location of fines with respect to the pores. 

The fundamental question asked when evaluating an exploration prospect is how much hydrocarbon resource is in place To answer this question, the conventional reservoir engineering approach is to compute the probable reservoir hydrocarbon pore volume, i.e. the size and extent of the hydrocarbon container , from estimates of reservoir rock and fluid properties. Uncertainties in the geological model, source rock characteristics, trapping mechanisms and seal rock effectiveness, and the presence of sufficient reservoir rock for commercial hydrocarbon production, are often represented as a singlevalued probability of success. 

Formation waters are often very saline, often containing more than 200 000 ppm total dissolved solids (Ryder et al. 1996). In addition, the in-situ connate water is most often present as an irreducible (non-mobile) water phase (Law 1984a,b, 1985 Ryder et al. 1996). The hydrocarbon properties vary depending on the type of BCGS, the source rock characteristics, and the effects of burial history on temperature and pressure gradients. 

The hydrocarbon mass remaining in the reservoir is calculated as the arithmetic difference between the hydrocarbon masses entering and leaving the reservoir. The hydrocarbon mass remaining in the reservoir reflects not only the source rock characteristics and hydrocarbon generation efficiency, but also the tortuosity of the hydrocarbon migration paths and the sealing efficieney of the reservoir rock. 

The site constants K and a are the functions of the effect of local rock characteristics on groundmotion. Constant K appliesto amplitude whereas a indicates vibration attenuation. The calculated site constants are listed in Table 2. The lower site constants for the secondary stope indicate that a lower amplitude vibration reached... 

Surrounding rock characteristics and lining scheme study for Qingyuan pumped storage power station tailrace tunnel... 

Side scan sonar is used to locate and identify man-made objects (shipwrecks, pipelines, cables, debris, etc.) on the seafloor and determine sediment and rock characteristics of the seafloor. The side scan sonar provides a sonogram of the seafloor that appears similar to a continuous photographic strip (Figure 7.13). A mosaic of the seafloor can be provided by overlapping the coverage of adjacent survey lines. 

Formation testers are measurement instruments that retrieve reservoir fluid samples from wells during pauses in drilling operations. Various practical questions arise. A type of reverse invasion problem appears how long must pumps be operated in order to obtain true formation fluids and not mud filtrate contaminants How do pump power requirements vary in permeable versus tight zones Can measured pressure transients be interpreted for rock characteristics like permeability and anisotropy Different answers are obtained depending on the fluid model assumed. Later in this book, we will consider constant density, immiscible, two-phase flows with and without mudcake effects. For now we assume transient, compressible, single-phase flow, but within this framework, we formulate and solve a very general problem. 

Continuous injection of polymer is to be considered with the same polymer and rock characteristics used in Problem 5.16. Will an oil bank form when polymer injection is started Why or why not ... 

The analyses from 23 cores were used to determine the reservoir rock characteristics. The analyses showed that the reservoir had two rock or permeability systems, with median permeabilities of 6.5 and 137 md (total weighted average of 38.8 md). The two rock systems were intermixed in the vertical column with the upper portion of the rock having higher average permeability than the lower portion. The lower-permeability system, with a median porosity of 9.5%, contained about 40% of the reservoir PV (flow capacity (kh), while the more piermeable system, with a median porosity of 16.3%, contained 60% of the PV and 95% of the total flow capacity. Capillary pressure... 

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