Thermal regime and Hydrocarbon generation in the Apsheron Trough of the South Caspian
Lomonosov Moscow State University, Earth Science Museum, Russian Federation, Russia
*Corresponding author: Galushkin Yu I, Lomonosov Moscow State University, Earth Science Museum, Russian Federation, Russia, Tel: +74959391594, E-mail: firstname.lastname@example.org
Received: June 9, 2018 Accepted: June 23, 2018 Published: June 28, 2018
Citation: Yu G. Thermal regime and Hydrocarbon generation in the Apsheron trough of the South Caspian. Int J Petrochem Res. 2018; 2(1): 150-154. doi: 10.18689/ijpr-1000126
Copyright: © 2018 The Author(s). This work is licensed under a Creative Commons Attribution 4.0 International License, which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited.
The earlier modeling helped explain the contradiction between the high thermal regime of the mantle of the South Caspian Basin and the abnormally low temperatures of the upper 6 km of its sedimentary blanket. The modeling suggested that the "oil window" is located at the depths from 4.5 to 9 km in the modern sections of the South Apsheron Trough and includes the rocks of the Productive and Pontian formations which are not source rocks in the basin. To solve this problem, we used reconstruction of the thermal history of the basin to restore numerically the history of realization of hydrocarbon potential of the Maikop and Diatomaceous formations. Our modeling shown that the non-steady thermal regime of the mantle in the region and avalanche sedimentation in the Pliocene-Quaternary have shifted the time of intense hydrocarbon generation close to the present time. The maximum generation of light oil by the rocks of the Maikop and Diatomaceous formations occurred for the last 2 to 7 million years when avalanche sedimentation in the Pliocene-Quaternary time took place in the Basin and the powerful layers of weakly compacted highly permeable rocks were created. Assuming the possibility of vertical migration through weakly compacted layers to the horizons with lower temperatures, it can be said that the Upper Maikop and Diatomaceous rocks are promising for the generation of liquid hydrocarbons (mainly of light oil) and gas. The modeling presented in this paper help to understand a leading contribution of the Maikop and Diatomaceous source formations to formation of oil and gas accumulations, despite these suites in present-day sedimentary section locate deeper than the "oil generation window".
Keywords: South Caspian, heavy and light oil generation, secondary cracking, vitrinite reflectance
The South Caspian basin is the one of the promising oil and gas regions of the world. The originality of the Basin is huge thickness of the sedimentary cover (over 20 km), the extremely high sedimentation rate in the Pliocene (up to 5 km in million years), and a low degree of compaction of the Pliocene-Quaternary sediments   . Thermal regime of the basin is also unusual. It is well known that the South Caspian Basin is characterized by abnormally low temperatures of the rocks in the upper 6 km of the sedimentary cover    . But at the same time, assessments of deep temperatures, as well as the study of the upper mantle by electrical and seismic sounding, show that the studied area is one of the most heated areas of the Caspian region along with the latitudinal belt of the Middle-Caspian   .
Application of the GALO system for basin modeling   allowed us to reconstruct the thermal history of sedimentary blanket of the South Caspian Basin in the South Apsheron Trough (Figure 1) and explain the contradictions between high thermal regime of the mantle and the low rock temperatures in the upper part of the sedimentary cover in the South Caspian Basin . Figure 2 demonstrates the part of general reconstruction of the burial and thermal history of the Basin for last 20 My. This reconstruction is in agreement with modern sedimentary section of the basin, established according to drilling data and seismic profiling    and with observed values of deep temperatures (Figure 3a) and vitrinite reflectance (Figure 3b). Analysis of the variations in the basin tectonic subsidence in  revealed two periods of intensive stretching of the lithosphere with amplitudes: β ≈ 1.4 and 1.7. These stretchings explain the intense basement subsidence during sedimentation in the Oligocene and Miocene, as well as the avalanche sedimentation in the Pliocene together
with sharp changes in the sea depth in this time  . As result of the above stretching periods, the total crust thickness reduced up to 32.4 km at present time, 20 km of which are the present-day sedimentary section. Therefore, a thickness of the consolidated crust decreased from initial 35 km to the present-day value of 12.4 km . The last value is close to the geophysical estimates of the thickness of the consolidated crust in the Basin   , and is in accordance with geophysical assessment of thickness of the granitic layer in the South Caspian lithosphere that admit the thickness of this layer no more than 2 - 6 km    .
Dotted lines in Figure 2 show the isolines of vitrinite reflectance. In our model, vitrinite reflectance was computed using the EASY-%Ro model of kinetic spectrum of vitrinite maturation from . The model of thermal evolution of the Basin in figures 2, 3b suggests that the "oil window" (0.50 < Ro < 1.30%) is located at depths from 4.5 to 9 km in the modern sedimentary sections of the South Apsheron Trough.
1- calculated values; 2 (left) - measured deep temperatures in western half of the South Caspian Basin   . 2 (right) - Ro-values measured in nearest well of the South Apsheron Trough; 3 - (left) - estimations of deep temperatures according to extrapolation-interpolation equations in . 3 (right) - indirect estimations of %Ro in the area under study by assessment of oil and gas maturity in  .
This depth interval includes the rocks of the Productive and Pontian formations (Figure 4). But these rocks are no source rocks, because they have very low TOC and contain mainly kerogen of the type III. Source rocks in the Basin are the deposits of the Diatomaceous and Maikop formations (Figure 4) that are outside the "oil window" according to the maturity level of organic matter. To explain this contradiction, we use the reconstructions of the thermal history of the sedimentary strata of the basin described in  to study a realization of the hydrocarbon potential in the rocks of the Maikop and Diatomaceous source formations.
Hydrocarbon generation by the Maikop and Diatomaceous source rocks The Maikop formation of age from 33.9 to 16 My occupies an interval of depths from 12.3 to 14.3 km in the modern section of the basin. Present-day content of organic matter is 2%.
and initial TOC is estimated in the model as 4.7%. According to modeling, the rocks at base of the formation reached temperature of about 280°C and maturity level of 3.98% by vitrinite
reflectance, whereas the rocks at top of the formation reached temperature of about 230°C and maturity level of Ro = 2.98% (Figure 5). The temperature and maturity level of the Maikop rocks are rather high and at present time the rocks can be considered as overmature gas prone source rocks. This is confirmed by Figure 6 shown that light and heavy oil have degraded totally to present time due to secondary cracking of kerogene. In these calculations, it was taken into account that kerogen of the Maikop shales is presented by mixture 50% marine kerogen of type II with initial potential of HC generation HI = 611 mg HC/g TOC and 50% kerogen of type III with initial potential of HC generation HI = 160 mg HC/g TOC, so that the initial potential of hydrocarbon generation of the rock is HI = 393.5 mg HC/g TOC. In calculations, we used the kinetic spectra for cracking of kerogen of types II and III in the 4-fractional model, that was developed in the French Oil Institute (Paris) and are applied in a widespread modeling package MATOIL.
Situation with Diatomaceous formation can be seen on Figures 7 and 8. The Diatomaceous formation of age from 16 to 7.2 My occupies an interval of depths from 9.7 to 12.3 km in the modern section of the basin. Present-day content of organic matter is 1% and initial TOC is estimated in the model as 2.4%. According to modeling, the rocks at base of the formation reached temperature of about 230°C and maturity level of Ro=2.98%, whereas the rocks at top of the formation reached temperature of about 190°C and maturity level of Ro = 1.74% (Figure 7). The temperature and maturity level of the Diatomaceous rocks are also rather high and at present time the rocks can be considered as high mature and gas prone source rocks. This is partly confirmed by Figure 8 shown that light and heavy oil in the rocks at base of formation have degraded totally to present time due to secondary cracking of kerogen (Figure 8). However, in the rocks at top of the Diatomaceous formation the light oil is degraded only partially (Figure 8).
Diatomaceous formations in the modern sedimentary section of the South Caspian Basin are mainly gas-generating. However, it is necessary to remember that the geochemical modeling in Figures 6 and 8 assumes that the generated hydrocarbons did not leave the pore space of the source rock. Therefore, only on the basis of present-day situation it cannot be argued that the prospects for the formation of oil fields generated by the rocks of the above formations are small. The fact is that the South Caspian Basin is an unusual sedimentary basin. Here, the unsteady character of thermal regime of the mantle  and avalanche sedimentation contributed to the displacement of the processes of maturation of organic matter to the present time. Of course, the rocks of the lower Maikop are mainly gas-generating. But the modeling shows that the secondary cracking of liquid hydrocarbons in the Upper Maikop rocks occurred only 5-10 million years ago and only 2 - 4 million years ago in the Diatomaceous rocks (Figures. 6, 8). Liquid hydrocarbons generated by these rocks could quite migrate 3-4 km vertically through the relatively weakly consolidated rocks of the upper layers and reach the Productive strata with a lower temperature, thereby avoiding P-T conditions of secondary cracking. Then the upper half of the Maikop formation can be considered as promising for the generation of both liquid and gas hydrocarbons. The probability of avoiding hard conditions of secondary cracking for the Diatomaceous rocks was even more because here degradation of heavy and light oils occurred during avalanche sedimentation in the Pliocene-Quaternary time when the powerful layers of weakly compacted highly permeable rocks were created . Assuming the possibility of such vertical migration through weakly compacted layers to the horizons with lower temperatures, it can be said that the Diatomaceous rocks are promising for the generation of liquid hydrocarbons (mainly of light oil) and gas.
The modeling suggests that the "oil window" is located at depths from 4.5 to 9 km in the modern sections of the Trough and includes the rocks of the Productive and Pontian formations. But these rocks are no source rocks, because they have very low TOC and contain mainly kerogen of the type III. Source rocks in the Basin are the deposits of the Diatomic and Maikop formations. We explain this contradiction by the fact that the non-steady thermal regime of the mantle in the region and avalanche sedimentation in the Pliocene- Quaternary had a significant influence on the history of hydrocarbon generation in the basin, shifting the time of intense hydrocarbon generation to the present time. According to the calculations, the maximum generation of light oil by the rocks of the Maikop and Diatomic formations occurred for the last 2 to 7 million years. Such recent hydrocarbon generation and significant role of vertical migration of hydrocarbons determine leading contribution of the Maikop and Diatomaceous suites to formation of oil and gas accumulations, despite these suites in present-day sedimentary section locate deeper than "oil generation window".
(2). The height of quartz sand bed was used as a parameter to control the residence time. With the increase of the residence time, the influence on the secondary pyrolysis of primary volatiles gradually weakened. The heavy components were converted into light components via contacting with silica sand. Within 1~3 seconds of the residence time, the cracking of aliphatic hydrocarbons intensified, while the gas yield increased significantly and mainly dominated by decomposition reactions. During the 3 to 5 seconds residence time, the yield of VGO components was significantly reduced. The rapid enrichment of gas and the presence of steam could suppress gas generation and this process mainly dominated by the condensation reactions.
(3). The addition of steam had an inhibitory effect on the polymerization of aromatics. The proportion of SAH monocyclic aromatics in the aromatic component after the addition of 20% steam was much higher than that without steam. This shows that the addition of steam could well inhibit the condensation of aromatics. In general, the regulation effect of steam on the secondary reactions of oil shale pyrolysis volatiles was not only reflected in the increase in oil yield but also could improve the content and quality of light components in oil products, which reduced the difficulty in the downstream processing of oil products.
The study was conducted with the research programs financed by National Natural Science Foundation (21406264), National Basic Research Program of China (2014CB744304) and Science Foundation of China University of Petroleum, Beijing (No. 2462018BJC003).
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