Heavy oil and natural bitumen deposits development is especially relevant nowadays. One of the highly efficient techniques for the development of such deposits is the steam-assisted gravity drainage (SAGD) method.
This work has two main objectives. The first is to build the geochemical model of a deposit on vertical and horizontal gradients of the relative content of biomarkers. And the second is to assess the feasibility of applying the derived model to monitor the development of superviscous oil deposits in the Karmalskiy deflection of the Cheremshanskoye deposit, where the SAGD technology is currently applied.
The experimental part of work consists of the extraction of 35 core samples fr om the 8 oil well pumps, extraction of the saturated factions from the bitumen and the gas chromatography-mass spectrometry (GCMS) analysis of the selected factions in the TIC mode.
The relative concentration of 6H-Farnesol (HHF) to Phytane (Ph) was selected as a simulation parameter. Laboratory studies have shown that the HHF/Ph ratio is shown in horizontal and vertical gradients due to biodegradation of the organic matter throughout the whole studied area. It is also noted that in almost all wells there is a sharp increase in the HHF/Ph value at the bottom of the productive layer at a depth of 150 to 160 meters, wh ere the most intense biodegradation of the organic matter occurs. Laboratory studies have shown that the HHF/Ph ratio is stable in the context of hydrothermal processing under pressure, which indicates that it can be measured in the superviscous oil produced by the SAGD method for subsequent comparison with the geochemical model.
Based on the constructed model and measured HHF/Ph ratios in the extracted superviscous oil, authors have assessed the likely ways of its tributaries to the extractive wells.
1. Khisamov R.S., The analytical model for development of heavy oil deposit by steam-assisted gravity drainage method (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2015, no. 2, pp. 62–64.
2. Bennett B., Adams J., The controls on the composition of biodegraded oils in the deep subsurface, Part 3. The impact of microorganism distribution on petroleum geochemical gradients in biodegraded petroleum reservoirs, Organic Geochemistry, 2013, V. 56, pp. 94–105.
3. Peters K.E., Walters C.C., Moldowan J.M., The biomarker guide, Cambridge U.K.: Cambridge University Press, 2005, 1155 p.
4. Feoktistov D., Sitnov S., Vahin A. et al., The description of heavy crude oils and the products of their catalytic conversion according to SARA-analysis data, International Journal of Applied Engineering Research, 2015, V. 10, pp. 45007 – 45014.
5. Sitnov S.A., Feoktistov D.A., Kayukova G.P. et al., Catalytic intensification of in-situ conversion of high-viscosity oil in thermal steam extraction methods, International Journal of Pharmacy and Technology, 2016, V. 8 (3), pp. 14884–14892.
6. Vakhin A.V., Onishchenko Ya.V., Chemodanov A.E. et al., Thermal transformation of bitumoid of Domanic formations of Tatarstan (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 10, pp. 32–34.
7. Sitnov S.A., Petrovnina M.S., Feoktistov D.A. et al., Intensification of thermal steam methods of production of heavy oil using a catalyst based on cobalt (In Russ.), Neftyanoe khozyaystvo = Oil Industry, 2016, no. 11, pp. 106–108.
8. Petrov S.M., Zakiyeva R.R., Ibrahim Abdelsalam Ya. et al., Upgrading of high-viscosity naphtha in the super-critical water environment, International Journal of Applied Engineering Research, 2015, V. 10 (24), pp. 44656–44661.
9. Sitnov S.A., Feoktistov D.A., Petrovnina M.S. et al., Structural changes of heavy oil in the composition of the sandstone in a catalytic and non-catalytic aquathermolysis, International Journal of Pharmacy and Technology, 2016, V. 8 (3), pp. 15074–15080.
10. Onishchenko Ya.V., Vakhin A.V., Voronina E.V., Nurgaliev D.K., Thermo-catalytic destruction of kerogen in the presence of cobalt oxide nanoparticles and mineral pyrite (In Russ.), SPE 181915-MS, 2016.