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Figure Captions

Methods

The analysis of maturity of organic matter (OM) was based on the optical method (analysis of vitrinite reflectance R₀). The methods of a direct estimation of maturity of oil and gas were carried out by using of appropriate isotope-geochemical parameters (Peters and Moldovan, 1993). Biomarker parameters such as the degree of C₂₉ sterane izomerization and methyl - phenanthrene index (MPI-1) were used during the estimation of maturity of oil. The values of these parameters were recalculated in equivalent R₀ values on the basis of experimental research results.

The estimation of maturity of gas is based on the experimentally revealed dependence between isotope composition of carbon (ICC) of HC gases and vitrinite reflectance (R₀) (Faber, 1987). The forecast of depth of the HC gases source location is given on the basis of this dependence and regularities of change of R₀ vs. depth in the South Caspian Basin. The estimations were carried out on ethane because the estimations on methane with relation to the influence of methane of a biochemical origin are less objective.

Results

OM Maturity

The results of the R₀ measurements in the South Caspian Basin are partially reflected in publications. However, the most important research was carried out by the Geology Institute of Azerbaijan National Academy of Sciences in cooperation with the foreign oil companies. The results of these studies for Paleogene-Miocene rocks generalized in the form of a bar chart of the R₀ values distribution are in Figure 1 A .

According to the bar chart, the R₀ modal values varies within the limits of 0.6-0.9% (about 50% of tested samples). In this connection it is possible to conclude that OM of the studied rocks is mainly on the initial stage and peak of maturity. Most probably, the values received are understated as a result of the influence of secondary processes and location of the rocks studied in the elevated marginal part of the basin. 

Oil Maturity

According to Guliyev et al. (2000) about 50% of the oil samples studied have values of maturity at C₂₉ sterane isomerization of 0.63-0.73% Req. Estimations based on the same parameter carried out by Abrams and Narimanov (1997) and Gurgey (2003) set Req values of 0.52-0.81 and 0.56-0.85 accordingly. Estimations at MPI carried out by Wavrek et al. (1996), Inan et al. (1998), Abdullaev et al. (1998), Кatz et al. (2000) and by the author of this presentation vary within the limits of 0.7-0.8%; 0.79-0.87%; 0.56-0.82%; 0.7-0.95% and 0.52-0.96% Req accordingly.  

In spite of the fact that the above estimations based on the data of the oil analyses were carried out in various laboratories using various parameters, they, as a whole, coincide with each other, reflecting an initial stage and peak of oil generation.

Peak maturity of oils (on Req) and OM (on R₀) as a whole coincide well with each other (see Figure 1 А, B₁, B₂), confirming objectivity of the calculated Req values.

It is interesting that the maturity of oil seepages related to mud volcanoes coincides with the maturity of Miocene-lower Pliocene reservoir oils. This leads to the conclusion that oils of the mud volcanoes are a product of destruction of oil accumulations in the noted reservoirs.

Maturity of Gases

Calculated values of Req of HC gases (at ethane) of fields in the South Caspian Basin (with the reservoirs depth occurrence interval of 501-5778 m) carried out by Katz et al. (2000) varies within the limits of 0.85-1.70% Req. The estimations carried out by the author of this presentation, as a whole, coincide with the estimations of Katz et al. (2000) characterized by Req values of 0.98-1.91%, except in 3 cases (from 56 tested samples) with Req of > 2.2% (Neftchala, wells 867 and 889; Absheron kupesi, well 42).

The maturity of HC gases from mud volcanoes as a whole coincide with the maturity of HC gases of reservoirs varying within the limits of 1.3-2.07% Req (Figure 1 C₁ and C₂). According to four measurements of maturity of HC gases of hydrates formed in submarine mud volcano craters in a deep-water part of the Southern Caspian sea varies within the limits of 1.47-1.94 % Req (Figure 1 C₃). Modal values of maturity of these gases, as well as gases of mud volcanoes and reservoirs, vary in the range of 1.5-2.0% Req.

Conclusions

Using all results of estimations of the oil and gas maturity and regularity of change of R₀ values with depth revealed for the South Caspian Basin (Wavrek et al. 1996), the summary model of vertical zoning of oil and gas formation (Figure 2) was constructed. According to this model, the generation of petroleum is located within the depth interval of 5-15 km; the interval of generation of oil occurs on the depth of 5-9 km (peak between 7-8 km), and gas in the depth range of 7-15 km (peak between 11-12 km).

It is important to note that the vertical zonality of oil and gas formation do not reflect zonality of their accumulation in reservoirs, which is caused by the process of intensive subvertical migration of HC fluids, having presumably injection character (Feyzullayev and Aliyeva, 2003). The distance of subvertical migration of most volume of oils is, presumably, 4 km (Figure 3 B). It is well known that source rocks and main reservoirs in the South Caspian Basin are related to various stratigraphic complexes, which is once again confirmed by the absence of dependence between depths of generation and accumulation of oils (Figure 3 A).

References

Abdullaev, T., M. L. Falt, A. Akhundov, W. G. van Grass, T. Kwamme, H. L. Flolo, K. Mehmendarov, A. A. Narimanov, S. T. Olsen, G. Seljeskog, O. Skontorp, T. Sultanzade, N. Tank, and E. Valieva, 1998, A reservoir model for the main Pliocene reservoirs of the Bahar Field in the Caspian Sea, Azerbaijan, Petroleum Geoscience, v. 4, p. 259–270.

Abrams, M.A., A.A. Narimanov, 1997, Geochemical evaluation of hydrocarbons and their potential sources in the western South Caspian depression, Republic of Azerbaijan, Marine and Petroleum Geology, v. 14, p. 451-468.

Faber, E.Z., 1987, Isotopengeochemie gasformiger Kohlenwasserstoffe: Erdole, Erdgas and Kohle, v. 103, p. 210-218 (in German).

Feyzullayev, A., Aliyeva Es, 2003, Estimation of the various source rocks contribution in oil pools formation, EAGE 65 Conference and Exhibition, Stavanger, The Norway, 2-5 June, Extended Abstracts CD, P 026.

Feyzullayev, A., I. Guliyev, M. Tagiyev, 2001, Source potential of the Mesozoic-Cenozoic rocks in the South Caspian Basin and their role in forming the oil accumulations in the Lower Pliocene reservoirs, Petroleum Geoscience, v. 7, p. 409-417.

Guliev I., A. Feyzullayev, D. Husseynov, 2000, Maturity degree of oils the different age reservoirs in the South Caspian megadepression, Geologia nefti i gasa, no. 3, p. 41-50 (in Russian).

Gurgey, K., 2003, Correlation, alteration, and origin of hydrocarbons in the GCA, Bahar, and Gum Adasi fields, western South Caspian Basin: geochemical and multivariate statistical assessments, Marine and Petroleum Geology, 21 p.

Inan, S., N.M. Yalcın, S. I. Guliev, K. Kuliev, and A.A. Feizullayev, 1998, Deep petroleum occurences in the Lower Kura depression, South Caspian Basin, Azerbaijan, An organic geochemical and basin modeling study, Marine and Petroleum Geology, v. 14, p. 731–762.

Katz, K.J., D. Richards, D. Long, and W. Lawrence, 2000, A new look at the components of the petroleum system of the South Caspian Basin, Journal of Petroleum Science and Engineering, v. 28, p. 161–182.

Peters, K.E., J.M. Moldovan, 1993, The biomarker guide: Interpreting molecular fossils in petroleum and ancient sediments, Prentice Hall, Englewood Cliffs, New Jersey, 363 p.

Wavrek, D., J. Collister, D. Curtiss, J. Quick , I. Guliyev, and A. Feyzullayev, 1996, Novel Application of Geochemical Inversion to Derive Generation/Expulsion Kinetic Parameters for the South Caspian Petroleum System (Azerbaijan), AAPG/ASPG Research Symposium, “Oil and gas petroleum systems in rapidly subsiding basins”, October 6-9, Baku, Azerbaijan.