Нефтегазовые нанотехнологии для разработки и эксплуатации месторождений. Часть 2. Евдокимов И.Н - 21 стр.

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Our experiments revealed noticeable transformations of the

macroscopic properties of native crudes at the temperature-defined

nanophase boundary “A” in Fig. 5. The left-hand part of Fig. 9

shows variations of the pour point of a Tatarstan crude after 1

hour thermal pre-treatments at temperatures close to the dis-

cussed phase boundary.

The crude had a density of 895 g/l, con-

tained ~3.5 wt. % asphaltenes, ~20 wt. % resins, ~0.3 wt. % waxes.

First deviations of the pour point became noticeable after pre-

treatment at ca. 30°C, while the most dramatic increase, from

−16.2 to +11.2°C, was registered after pre-treatment at tempera-

ture of 37.5°C.

Fig. 9. Strong variation of native crude oil properties at asphaltene

nanophase boundary “A” in Fig. 5.

The right-hand part of Fig. 9 shows dramatic density stratifi-

cation near the discussed asphaltene nanophase boundary “A” in

10 cm-high samples of a Yamal native crude (West Siberia), stored

at various temperatures. Density variations were evaluated via re-

fractive index (RI) measurements in the minute quantities of oil

extracted from the top and from the bottom of the sample. In the

absence of “phase boundary” phenomena, an expected effect is a