Sands hydrocarbon bearing

Fig. 5. CSP calibration. The data for this calibration were gathered on 91 reservoirs along 10 faults in three different fields. Comparing the CSP in hydrocarbon bearing sand to sand windows with those in water bearing sand to sand windows results in a fault seal probability curve. The fault seal probability increases with increasing CSP up to a certain value above which sealing is independent of CSP.

Fig. 4 also includes total (thermal) gas curves for the wells, showing the increased gas levels accompanying the undercompacted Rogaland and Hordaland Group claystones (causing increased amplitudes at the Top Paleocene seismic reflector above the structure), and the Jurassic hydrocarbon bearing sands. 

Fig. 4. North-south seismic line shown in Figure 3 illustrating the stratigraphic and structural aspects of the Magnolia Field. Miocene-age hydrocarbon-bearing sands are loeated elsewhere in the field.

Represents interval that is potentially hydrocarbon bearing. Properties of individual West Sak sand members are listed in Tables 2-6. 

The sand-shale sequence containing a thinly laminated section at the depth interval x210-255 can be easily identified by very high anisotropy ratios >8 (Track 1). Track 2 presents the resistivities. In the section, the horizontal resistivity is dominated by the lower resistivity shale. In the laminated interval, the horizontal resistivity shows very modest increase to 1.0-1.3 Q m, while the vertical resistivity is over a decade higher (up to 20 Q m), indicating the presence of hydrocarbon-bearing sand laminations. 

Zemanek, J., 1989. Low-resistivity hydrocarbon-bearing sand reservoirs. SPE Form. Eval. 4, 515-521. December. 

Distinctions between tar sands bitumens and heavy oils are based largely on differences in viscosities. The bitumen in oil sand has a specific gravity of less than 0.986 g/mL (12°API), and thus oil sands may be regarded as a source of extremely heavy cmde oil. Whereas heavy oils might be produced by the same techniques used for the lighter cmde oils, the bitumens in tar sands are too viscous for these techniques. Consequently these oil-bearing stones have to be mined and specially processed to recover contained hydrocarbon. 

The Extraksol process can extract organic contaminants such as oils and greases, polynuclear aromatic hydrocarbons (PAHs), pentachlorophenols (PCPs), and phenols from a variety of solid matrices. The Extraksol process can extract polychlorinated biphenyls (PCBs) from clay-bearing soil, sand, and FuUer s earth. Extraksol has successfully treated various media such as activated carbons, refinery sludges, and wood treatment sludges. 

In this period, a start was made on the study of fault zones. On the Gulf Coast, it had already been noticed that faults can separate oil or gas accumulations from water-bearing sands. Hubbert, in deriving the theoretical concepts of petroleum trapping, had shown that the boundary of a reservoir rock is a barrier to hydrocarbon migration because of its capillary properties (Hubbert, 1953). Observations of fault zone material showed the effect of cataclasis but also the presence of smeared-in shale. 

Fig. 5 and 6 in Chapter 3). It is particularly common in pumps, valves, and mechanical seals that are working in abrasive slurries such as sand, water, and hydrocarbons found in oil and gas extraction. The condition is typified by a crushing and grinding action between the surfaces, perhaps the two sliding surfaces of a journal bearing, which breaks down the abrasive particles and continuously creates new cutting edges. When combined with corrosion this creates a very extreme wear situation. 

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