Thematic index of articles

Journal V.24.No.4.2022
Pages
Download article

Potential for improving the efficiency of terrigenous oil deposits waterflooding with the use of low salinity technology at fields of the Tatarstan Republic

Z.R. Saptarova, A.A. Mamonov, S.A. Usmanov, A.A. Lutfullin, V.A. Sudakov, M.S. Shipaeva, A.A. Shakirov

Original article

DOI https://doi.org/10.18599/grs.2022.4.7

82-90
rus.

open access

Under a Creative Commons license
This article is devoted to the review of one of the currently relevant methods of enhanced oil recovery – low-salinity waterflooding (LSW) – on the example of terrigenous Tulian, Bobrikovian and Devonian reservoirs of the Tatarstan Republic fields.

The first part of review contains information about the key processes underlying this method, such as swelling and migration of clay particles and wettability alteration, as well as the mechanisms that explain these processes, which include cation exchange, multicomponent ion exchange, electric double layer expansion, etc. Their understanding, in turn, contributes to the identification of the main factors, the presence or absence of which at the field allows us to give a preliminary assessment of LSW application. There are main factors: the presence of clay particles, a significant content of Ca2+ and Mg2+ ions, as well as multivalent ions in formation water, low formation permeability, reduced oil viscosity, an increased content of acidic and especially basic components in oil and, as a result, a hydrophobic type of initial rock wettability.

Then, examples of using the method in other fields are given and the results of laboratory studies, including the measurement of the contact angle, core flooding experiments, are briefly highlighted.

A preliminary screening is carried out on the basis of geological and field data from several fields of Tatarstan Republic, candidate fields are identified and a preliminary conclusion about LSW application in this region is made. The positive factors for the reservoirs under consideration, identified at the preliminary screening stage, include low formation temperature, high salinity of formation water with a significant content of divalent cations and the potential to shift the pH level from the current slightly acidic level towards increased alkalinity, and an increased content of polar oil components. In addition, the reservoirs of the Tulian and Bobrikovian horizons are characterized by the presence of clay particles, and the Devonian reservoir are characterized by a reduced oil viscosity coupled with an increased oil base number.
 
low-salinity waterflooding, wettability, Tulian horizon, Bobrikovian horizon, Devonian period
 
  • Abdallah, W. et al. (2007). Fundamentals of Wettability. Schlumberger, Oilfield Review, pp. 44–61. https://www.slb.com/-/media/files/oilfield-review/p44-61-english
  • Akhmetgareev V.V. (2016). Investigation of the processes of oil reservoirs development by low-salinity waterflooding based on modeling (on the example of fields in the Republic of Tatarstan). Bugulma, 135 p. (In Russ.)
  • Al-Shalabi P.E., Emad. (2015). A Comprehensive Review of Low Salinity/Engineered Water Injections and their Applications in Sandstone and Carbonate Rocks. Journal of Petroleum Science and Engineering, 139. https://doi.org/10.1016/j.petrol.2015.11.027
  • Antoniadi D.G., Savenok O.V., Bukov N.N. et al. (2014). The possibility of using low-salinity water for increasing oil fields in Krasnodar region, Gornyy informatsionno-analiticheskiy byulleten, 8, pp. 331–339. (In Russ.)
  • Austad, Tor. (2013). Water-Based EOR in Carbonates and Sandstones: New Chemical Understanding of the EOR Potential Using «Smart Water». Enhanced Oil Recovery Field Case Studies, pp. 301–335. https://doi.org/10.1016/B978-0-12-386545-8.00013-0
  • Bartels W.-B., Mahani H., Berg S., Hassanizadeh S.M. (2019). Literature Review of Low Salinity Waterflooding from a Length and Time Scale Perspective. Fuel, 236, pp. 338–353. 1https://doi.org/10.1016/j.fuel.2018.09.018
  • Chavan, M., Dandekar, A., Patil, S. et al. (2019). Low-salinity-based enhanced oil recovery literature review and associated screening criteria. Pet. Sci., 16, pp. 1344–1360. https://doi.org/10.1007/s12182-019-0325-7
  • Jackson M.D., Vinogradov Jan, Hamon Gerald, Chamerois Manuel (2016). Evidence, mechanisms and improved understanding of controlled salinity waterflooding part 1: Sandstones. Fuel, 185, pp. 772–793. https://doi.org/10.1016/j.fuel.2016.07.075
  • Igdavletova M., Ismagilov T., Ganiev I., Telin A. (2015). Influence of salinity of injected water on permeability and oil recovery of reservoirs. (In Russ.) https://neftegaz.ru/science/development/331660-vliyanie-mineralizatsii-zakachivaemoy-vody-na-pronitsaemost-i-nefteotdachu-kollektorov
  • Kakati Abhijit & Sangwai Jitendra (2018). Wettability Alteration of Mineral Surface during Low Salinity Water Flooding: Role of Salt Type, Pure Alkanes and Model Oils Containing Polar Components. Energy Fuels, 32(3), pp. 3127–3137. https://doi.org/10.1021/acs.energyfuels.7b03727
  • Kuznetsov A.M., Kuznetsov V.V., Bogdanovich N.N. (2011). On the question of preserving natural wettability of a core taken from wells. Neftyanoe khozyaystvo = Oil industry, 1. (In Russ.)
  • Lager A., Webb K.J., Black C.J.J., Singleton M., Sorbie K.S. (2008). Low Salinity Oil Recovery – An Experimental Investigation. Petrophysics, 49.
  • Mamonov Aleksandr, Puntervold Tina & Skule Strand (2017). EOR by Smart Water Flooding in Sandstone Reservoirs – Effect of Sandstone Mineralogy on Initial Wetting and Oil Recovery. SPE Russian Petroleum Technology Conference. Moscow, Russia. https://doi.org/10.2118/187839-MS
  • McMillan Marcia, Rahnema Hamid, Romiluy Johnson, Kitty Fitzgerald (2016). Effect of exposure time and crude oil composition on low-salinity water flooding. Fuel, 185, pp. 263–272. https://doi.org/10.1016/j.fuel.2016.07.090
  • Mikhailov N.N., Motorova K.A., Sechina L.S. (2016). Geological factors of wettability of oil and gas reservoir rocks. (In Russ.) https://magazine.neftegaz.ru/articles/prikladnaya-nauka/626760-geologicheskie-faktory-smachivaemosti-porod-kollektorov-nefti-i-gaza
  • Morrow, Norman, Buckley, Jill. (2011). Improved Oil Recovery by Low-Salinity Waterflooding. J Pet Technol, 63, pp. 106–112. https://doi.org/10.2118/129421-JPT
  • Nasralla, Ramez A., Bataweel, Mohammed A., Hisham A. Nasr-El-Din (2013). Investigation of Wettability Alteration and Oil-Recovery Improvement by Low-Salinity Water in Sandstone Rock. Journal of Canadian Petroleum Technology, 52, pp. 144–154. https://doi.org/10.2118/146322-PA
  • Piñerez Torrijos I. D., Mamonov A., Strand S., Puntervold T. (2020). The role of polar organic components in dynamic crude oil adsorption on sandstones and carbonates. CT&F – Ciencia, Tecnologia y Futuro, 10(2), pp. 5–16. https://doi.org/10.29047/01225383.251
  • Skrettingland, K., Holt, T., Tweheyo, M.T., Skjevrak I. (2010). Snorre Low Salinity Water Injection - Core Flooding Experiments and Single Well Field Pilot. SPE Improved Oil Recovery Symposium. Tulsa, Oklahoma, USA. https://doi.org/10.2118/129877-MS
  • Snosy, M.F., Abu El Ela, M., El-Banbi, A. et al. (2020). Comprehensive investigation of low-salinity waterflooding in sandstone reservoirs. J Petrol Explor Prod Technol, 10, pp. 2019–2034. https://doi.org/10.1007/s13202-020-00862-z
  • Strand Skule, Puntervold Tina, Austad Tor (2016). Water based EOR from Clastic Oil Reservoirs by Wettability Alteration: A Review of Chemical Aspects. Journal of Petroleum Science and Engineering, 146, pp. 1079–1091. https://doi.org/10.1016/j.petrol.2016.08.012
  • Suijkerbuijk, B.M., Sorop, T.G., Parker, A.R., Masalmeh, S.K., Chmuzh, I.V., Karpan, V.M., Volokitin, Y.E., and A.G. Skripkin (2014). Low Salinity Waterflooding at West Salym: Laboratory Experiments and Field Forecasts. SPE EOR Conference at Oil and Gas West Asia. Muscat, Oman. https://doi.org/10.2118/169691-MS
  • Turgazinov I.K. (2018). Improving the efficiency of the development of oil fields in the late stages of operation using low-salinity waterflooding (on the example of the South Turgay field). Dr. sci. diss. (In Russ.)
  •  
Zalina R. Saptarova – Engineer, Hard-to-Recover Reserves Simulation Research and Educational Center, Institute of Geology and Petroleum Technology, Kazan Federal University
Bolshaya Krasnaya str., 4, Kazan, 420111, Russian Federation
 
Alexander A. Mamonov – Researcher, University of Stavanger, Stavanger, Norway
Norway, Stavanger, 4033
 
Sergey A. Usmanov – Deputy Director, Hard-to-Recover Reserves Simulation Research and Educational Center, Institute of Geology and Petroleum Technology, Kazan Federal University
Bolshaya Krasnaya str., 4, Kazan, 420111, Russian Federation
 
Azat A. Lutfullin – Cand. Sci. (Engineering), Deputy Head of the Department of Field Development, Tatneft-Dobycha, Tatneft PJSC
Lenin str., 75, Almetyevsk, 423450, Russian Federation
 
Vladislav A. Sudakov – Deputy Director of the Institute for Innovations, Director of Hard-to-Recover Reserves Simulation Research and Educational Center, Institute of Geology and Petroleum Technology, Kazan Federal University
Bolshaya Krasnaya str., 4, Kazan, 420111, Russian Federation
 
Maria S. Shipaeva – Technical Director, Geoindikator JSC; Engineer, Hard-to-Recover Reserves Simulation Research and Educational Center, Institute of Geology and Petroleum Technology, Kazan Federal University
Bolshaya Krasnaya str., 4, Kazan, 420111, Russian Federation
 
Artur A. Shakirov – General Director, Geoindikator JSC; Deputy Director, Hard-to-Recover Reserves Simulation Research and Educational Center, Institute of Geology and Petroleum Technology, Kazan Federal University
Bolshaya Krasnaya str., 4, Kazan, 420111, Russian Federation
 

For citation:

Saptarova Z.R., Mamonov A.A., Usmanov S.A., Lutfullin A.A., Sudakov V.A., Shipaeva M.S., Shakirov A.A. (2022). Potential for improving the efficiency of terrigenous oil deposits waterflooding with the use of low salinity technology at fields of the Tatarstan Republic. Georesursy = Georesources, 24(4), pp. 82–90. https://doi.org/10.18599/grs.2022.4.7

© 2023 The Authors. Published by Georesursy LLC