مقایسه و شبیه‌سازی روش‌های ازدیاد برداشت نفت پایه آبی در مخازن کربناته شکاف‌دار به‌روش تک بلوکه

نوع مقاله : مقاله پژوهشی

نویسندگان

پژوهشکده مطالعات مخزن، پردیس توسعه صنایع بالادستی نفت، پژوهشگاه صنعت نفت، تهران، ایران

چکیده

در مخازن شکاف‌دار، بخش آب‌روفته به‌عنوان ناحیه بین سطح تماس اولیه و جدید آب و نفت معرفی می‌شود. در این ناحیه شکاف‌ها به طور نسبتا کامل اشباع از آب می‌باشند و بلوک‌های سنگ حاوی نفت را احاطه می‌کنند. با توجه به ایجاد ناحیه آب‌روفته و باقی‌ماندن حجم زیادی از نفت درون سنگ، ضرورت استفاده از روش‌های نوین ازدیاد برداشت برای افزایش میزان بازدهی مخزن را افزایش می دهد. با توجه به پیچیدگی ذاتی مخازن شکاف‌دار و ضرورت پایداری تولید ازاین مخازن، انتخاب روش مناسب ازدیاد برداشت نیازمند مطالعات و شبیه‌سازی‌های متعدد می‌باشد. هدف از انجام پژوهش حاضر، بررسی اثر سه روش ازدیاد برداشت پایه آبی  شامل تزریق آب کم‌شور، سورفکتانت و آب کربناته بر افزایش تولید نفت از بخش آب‌روفته و آنالیز حساسیت پارامتر های موثر بر سازوکار تولید با استفاده از مدل تک بلوکه می‌باشد. برای ساخت مدل تک بلوکه از نرم‌افزار اکلیپس استفاده شده است. در این مدل بلوک سنگ توسط شکاف‌ها احاطه شده و جریان نفت از بلوک سنگ به شکاف و آب از شکاف به سنگ می‌باشد. نتایج به‌دست آمده نشان می‌دهد که زمان‌های افزایش بازیافت حاصل شده از چند ده سال تا چند صد سال تغییر می‌نماید که نشانگر سرعت بسیار پایین پدیده آشام و گرانش می‌باشد. با درنظر گرفتن زمان‌های بالا که خارج از طول عمر مخزن می‌باشد، تزریق‌های آب پایه اقتصادی به‌نظر نمی‌رسد. براساس نتایج، دامنه میزان افزایش بازیافت در حالت بسیار خوش بینانه تزریق آب کم‌شور (100 برابر رقیق‌شده آب دریا) در تزریق ثالثیه از 08/4% تا 6/49% می‌باشد. همچنین دامنه میزان افزایش بازیافت تزریق سورفکتانت در حالت بیشینه (غلظت ppm 10000)، در روش تزریق ثالثیه از صفر تا 8/13% می‌باشد. در تزریق آب کربناته نیز به‌صورت ثالثیه میزان افزایش بازیافت نفت از 47/0% تا 6/3% تغییر می‌نماید.

کلیدواژه‌ها

موضوعات

عنوان مقاله [English]

Comparison and Simulation of Various Methods for Increasing Oil Recovery in Fractured Carbonate Reservoirs Using Water-Based Techniques through the Single Block Method

نویسندگان [English]

  • Alireza Tajik Mansouri
  • Mohammad Parvazdavani
  • Shima Ebrahimzadeh
  • Shahab Gerami
  • Faramarz Nasirzadeh
Reservoir Studies Research Institute, Upstream Section, Research institute of petroleum industry (RIPI), Tehran,
چکیده [English]

More than half of the reservoirs in the world are carbonate reservoirs, most of which are fractured. The main controller of fluid flow and production in this kind of reservoirs is fracture. In fractured reservoirs, the water invaded zone is introduced as the zone between the initial and new contact surface of water and oil. In this zone, the fractures are completely saturated with water and surround the matrix blocks containing oil. Due to the pressure drop in these reservoirs compared to the initial pressure and the creation of a water invaded zone, as well as the remaining large volume of oil in the matrix, the necessity of using new methods of increased extraction to enhance the reservoir›s efficiency is evident. Considering the inherent complexity of fractured reservoirs and the need for stable production from these reservoirs, choosing the appropriate method for increased harvesting requires numerous studies and simulations. The purpose of this research is to investigate the effect of different the enhancing the oil recovery methods (three methods of increasing extraction of water-based with higher priority of primary screening) on the increase oil production from the water invaded zone and perform the sensitivity analyze on the parameters affecting the production mechanism using the single block model. The obtained results show that the recovery time varies from several tens of years to several hundreds of years, indicating a very low speed of the gravity phenomenon. Considering the above times that are outside the lifetime of the reservoir, water injections methods do not seem economical. Based on the results, the range of increased recovery in the very optimistic case of low salt water injection (100 times diluted sea water) in tertiary injection is from 4.08% to 6.49%. Additionally, the range of increase in surfactant injection recovery in the maximum state (concentration 10,000 ppm) in the tertiary injection method is from zero to 8.13%. In carbonated water injection, the rate of oil recovery increases from 0.47% to 3.6%.

کلیدواژه‌ها [English]

  • Base Enhance Oil Recovery
  • Fracture carbonate reservoirs
  • Low salinity water (LSW)
  • Surfactant
  • Carbonated water

مراجع

[1]. Aljuboori, F. A., Lee, J. H., Elraies, K. A., & Stephen, K. D. (2019). Gravity drainage mechanism in naturally fractured carbonate reservoirs; review and application. Energies, 12(19), 3699. doi.org/10.3390/en12193699.##
[2]. Madani, M., & Alipour, M. (2022). Gas-oil gravity drainage mechanism in fractured oil reservoirs: surrogate model development and sensitivity analysis. Computational Geosciences, 26(5), 1323-1343. ##
[3]. An, S., Erfani, H., Godinez‐Brizuela, O. E., & Niasar, V. (2020). Transition from viscous fingering to capillary fingering: Application of GPU‐based fully implicit dynamic pore network modeling. Water Resources Research, 56(12), e2020WR028149. doi.org/10.1029/2020WR028149. ##
[4]. Erfani, H., Karimi Malekabadi, A., Ghazanfari, M. H., & Rostami, B. (2021). Experimental and modelling study of gravity drainage in a three-block system. Transport in Porous Media, 136(2), 471-494. ##
[5]. Aghabarari, A., & Ghaedi, M. (2019). A new simulation approach to investigate reinfiltration phenomenon in fractured porous media. Journal of Petroleum Science and Engineering, 181, 106182. doi.org/10.1016/j.petrol.2019.106182. ##
[6]. Alipour, M., & Madani, M. (2023). New empirical scaling equations for oil recovery by free fall gravity drainage in naturally fractured reservoirs. Energy Geoscience, 4(3), 100190. doi.org/10.1016/j.engeos.2023.100190. ##
[7]. Jerauld, G. R., Lin, C. Y., Webb, K. J., & Seccombe, J. C. (2008). Modeling low-salinity waterflooding. SPE Reservoir Evaluation & Engineering, 11(06), 1000-1012. doi.org/10.2118/102239-PA. ##
[8]. Alameri, W., Teklu, T. W., Graves, R. M., Kazemi, H., & AlSumaiti, A. M. (2015, April). Experimental and numerical modeling of low-salinity waterflood in a low permeability carbonate reservoir. In SPE Western Regional Meeting (pp. SPE-174001). SPE. doi.org/10.2118/174001-MS. ##
[9]. Evje, S., Hiorth, A., Madland, M. V., & Korsnes, R. I. (2009). A mathematical model relevant for weakening of chalk reservoirs due to chemical reactions. Networks Heterog. Media, 4(4), 755-788. doi:10.3934/nhm.2009.4.755. ##
[10]. Joel, T., Patrick V. Brady, Barati Ghahfarokhi R. (2020). Review of low salinity waterflooding in carbonate rocks: 2 mechanisms, Investigation Techniques, and Future Directions. doi.org/10.1016/j.cis.2020.102253. ##
[11]. Seyyedi, M., Tagliaferri, S., Abatzis, J., & Nielsen, S. M. (2018). An integrated experimental approach to quantify the oil recovery potential of seawater and low-salinity seawater injection in North Sea chalk oil reservoirs. Fuel, 232, 267-278. doi.org/10.1016/j.fuel.2018.05.158. ##
[12]. Nasralla, R. A., Sergienko, E., Masalmeh, S. K., van der Linde, H. A., Brussee, N. J., Mahani, H., Suijkerbuijk, B.M. & Al-Qarshubi, I. S. (2016). Potential of low-salinity waterflood to improve oil recovery in carbonates: Demonstrating the effect by qualitative coreflood. Spe Journal, 21(05), 1643-1654. doi.org/10.2118/172010-PA. ##
[13]. Afekare, D. A., & Radonjic, M. (2017). From mineral surfaces and coreflood experiments to reservoir implementations: Comprehensive review of low-salinity water flooding (LSWF). Energy & fuels, 31(12), 13043-13062. doi.org/10.1021/acs.energyfuels.7b02730. ##
[14]. Hirasaki, G. J., Miller, C. A., & Puerto, M. (2011). Recent advances in surfactant EOR. SPE journal, 16(04),
889-907, doi.org/10.2118/115386-PA. ##
[15]. Sheng, J. J. (2015). Status of surfactant EOR technology. Petroleum, 1(2), 97-105. doi.org/10.1016/j.petlm.2015.07.003.
[16]. Iglauer, S., Wu, Y., Shuler, P., Tang, Y., & Goddard III, W. A. (2010). New surfactant classes for enhanced oil recovery and their tertiary oil recovery potential. Journal of Petroleum science and Engineering, 71(1-2), 23-29. doi.org/10.1016/j.petrol.2009.12.009. ##
[17]. Pashley R.M. & Karaman M. E. (2005). Surfactants and self-assembly, applied colloid and surface chemistry, John Wiley & Sons, Ltd, 978-0-47001-470-7, 61–77, doi.org/10.1002/0470014709.ch4. ##
[18]. Negin, C., Ali, S., & Xie, Q. (2017). Most common surfactants employed in chemical enhanced oil recovery. Petroleum, 3(2), 197-211. doi.org/10.1016/j.petlm. 2016.11.007. ##
[19]. T.W. Teklu, W. Alameri, H. Kazemi, R.M. Graves, A.M. AlSumaiti, Low salinity water-Surfactant-CO2 EOR, Petroleum 3 (3) (2017) 309–320, doi.org/10. 1016/j.petlm.2017.03.003. ##
[20]. Al-Sulaimani, H., Al-Wahaibi, Y., Al-Bahry, S., Elshafie, A., Al-Bemani, A., Joshi, S. and Ayatollahi, S., (2012). Residual-oil recovery through injection of biosurfactant, chemical surfactant, and mixtures of both under reservoir temperatures: induced-wettability and interfacial-tension effects. SPE Reservoir Evaluation & Engineering, 15(02), 210-217. ##
[21]. Ayatollahi, Sh. (2012). Residual-oil recovery through injection of biosurfactant, chemical surfactant, and mixtures of both under reservoir temperatures: induced-wettability and interfacial-tension effects. SPE Reservoir Evaluation & Engineering. 15 (02):210–7. doi:10.2118/158022-PA. ##
[22]. قجاوندی ح. و علیرضا نورمحمد، ع. ر. (2013). ازدیاد برداشت نفت از سنگ کربناته به‌وسیله آشام خودبه‌خودی محلول سورفکتانت، نشریه شیمی و مهندسی شیمی ایران، 32، 1392. ##
[23]. Daoshan, L., L. Shouliang, L. Yi, and W. Demin. 2004. The effect of biosurfactant on the interfacial tension and adsorption loss of surfactant in ASP flooding. Colloids and Surfaces A: Physicochemical and Engineering Aspects 244 (1-3):53–60. doi: 10.1016/j.colsurfa.2004.06.017. ##
[24] Collins, A. G., & Wright, C. C. (1985). Enhanced oil recovery injection waters. Chapter 6, 1st edition, In Developments in Petroleum Science, Elsevier., 151-221. doi.org/10.2118/6603-MS. ##
[25]. Dong, Y., Dindoruk, B., Ishizawa, C., Lewis, E.J., Kubicek, T. (2011). An experimental investigation of carbonated water flooding, SPE Annual Technical Conference and Exhibition. SPE paper No. 145380, October. doi.org/10.2118/145380-MS. ##
[26]. Hickok, C. W., & Ramsay, H. J. (1962, May). Case histories of carbonated waterfloods in Dewey-Bartlesville field. In SPE Secondary Recovery Symposium (pp. 333-MS). ##
[27]. Derakhshanfar, M., Nasehi, M., & Asghari, K. (2012, February). Simulation study of CO2-assisted waterflooding for enhanced heavy oil recovery and geological storage. In Carbon Management Technology Conference (pp. CMTC-151183). CMTC. doi.org/10.7122/151183-MS. ##
[28]. Sheng, J. J. (2014). Critical review of low-salinity waterflooding. Journal of Petroleum Science and Engineering, 120, 216-224. doi.org/10.1016/j.petrol.2014.05.026. ##
[29]. Yu, L., Evje, S., Kleppe, H., Kårstad, T., Fjelde, I., & Skjaeveland, S. M. (2009). Spontaneous imbibition of seawater into preferentially oil-wet chalk cores—Experiments and simulations. Journal of petroleum science and engineering, 66(3-4), 171-179. doi.org/10.1016/j.petrol.2009.02.008. ##
[30]. Jerauld, G. R., Lin, C. Y., Webb, K. J., & Seccombe, J. C. (2008). Modeling low-salinity waterflooding. SPE Reservoir Evaluation & Engineering, 11(06), 1000-1012. doi.org/10.2118/102239-PA. ##
[31]. Andersen, P. Ø., Evje, S., Kleppe, H., & Skjæveland, S. M. (2015). A model for wettability alteration in fractured reservoirs. SPE Journal, 20(06), 1261-1275. doi.org/10.2118/174555-PA. ##
[32]. Karimi, M., Al-Maamari, R. S., Ayatollahi, S., & Mehranbod, N. (2015). Mechanistic study of wettability alteration of oil-wet calcite: The effect of magnesium ions in the presence and absence of cationic surfactant. Colloids and Surfaces A: Physicochemical and Engineering Aspects, 482, 403-415. doi.org/10.1016/j.colsurfa.2015.07.001. ##
[33]. Salehi, M., Johnson, S. J., & Liang, J. T. (2008). Mechanistic study of wettability alteration using surfactants with applications in naturally fractured reservoirs. Langmuir, 24(24), 14099-14107. doi.org/10.1021/la802464u. ##
[34]. Standnes, D. C., & Austad, T. (2000). Wettability alteration in chalk: 2. Mechanism for wettability alteration from oil-wet to water-wet using surfactants. Journal of Petroleum Science and Engineering, 28(3), 123-143. ##
[35]. Strand, S., Standnes, D. C., & Austad, T. (2003). Spontaneous imbibition of aqueous surfactant solutions into neutral to oil-wet carbonate cores: Effects of brine salinity and composition. Energy & fuels, 17(5), 1133-1144. doi.org/10.1021/ef030051s. ##
[36]. Gupta, R., & Mohanty, K. (2010). Temperature effects on surfactant-aided imbibition into fractured carbonates. SPE Journal, 15(03), 588-597. doi.org/10.2118/110204-PA. ##
[37]. Delshad, M., Najafabadi, N. F., Anderson, G. A., Pope, G. A., & Sepehrnoori, K. (2009). Modeling wettabilityalteration by surfactants in naturally fractured reservoirs. SPE Reservoir Evaluation & Engineering, 12(03), 361-370. doi.org/10.2118/100081-PA. ##
[38]. Dong, Y., Dindoruk, B., Ishizawa, C., Lewis, E., & Kubicek, T. (2011, October). An experimental investigation of carbonated water flooding. In SPE Annual Technical Conference and Exhibition? (pp. SPE-145380). SPE. doi.org/10.2118/145380-MS. ##
[39]. Salehi, M. (2009). Enhancing the spontaneous imbibition process in naturally fractured reservoirs through wettability alteration using surfactants: mechanistic study and feasibility of using biosurfactants produced from agriculture waste streams (Doctoral dissertation, University of Kansas). ##
[40]. Yousef, A. A., Al-Saleh, S., Al-Kaabi, A., & Al-Jawfi, M. (2010, October). Laboratory investigation of novel oil recovery method for carbonate reservoirs. In SPE Canada Unconventional Resources Conference (pp. SPE-137634). SPE. doi.org/10.2118/137634-MS. ##
[41]. Salehi, M. 2009. Enhancing the Spontaneous Imbibition Process in Naturally Fractured Reservoirs through Wettability Alteration Using Surfactants: Mechanistic Study and Feasibility of Using Biosurfactants Produced from Agriculture Waste Streams. PhD Thesis, University of Kansas, pp. ##
[42]. Chang, Y. B., Coats, B. K., & Nolen, J. S. (1996, March). A compositional model for CO2 floods including CO2 solubility in water. In SPE Permian Basin Oil and Gas Recovery Conference (pp. SPE-35164). SPE. doi.org/10.2118/35164-MS. ##
پژوهش نفت
دوره 35، 1404-4 - شماره پیاپی 143
مهر و آبان 1404
صفحه 99-124

فایل ها

هم رسانی

ارجاع به این مقاله

آمار