Bakken油藏注气方式的模拟与预测

doi:10.11885/j.issn.1674-5086.2021.03.14.01

摘要/Abstract

摘要： Bakken储层是一种极致密油藏，具有低孔隙度、低渗透率的特点。以加拿大萨斯喀彻温省东南部地区Viewfield油田为例，利用Bakken致密储层及裂缝特征，通过建立10口相关油井的地质模型并进行数值模拟实验，来确定有效的注气方式对提高致密油采收率的可靠性和可行性。历史拟合的结果验证了数值模型与试验区实际生产数据和压力变化保持一致，确保了模型的有效性。同时，模拟研究评估了多种采收方案，如水驱法、二氧化碳气驱、水气交替法（CO₂-WAG）以及甲烷气驱对采收率的影响。目前研究结果表明，对累计产油量最敏感的两个参数是相对油水渗透率（K_row）和原生水饱和度（S_wcon）。其他对采收率影响较大的参数分别是二氧化碳的注入速率、水气交替循环次数、总注入次数和吸收时间。通过对比不同的采收方式，循环周期为两年的水气交替注入法对提高采收率的效果最好，其原油采收增产率可达5.033%。本次研究基于历史拟合的结果，预测、比较了不同注气方式对提高Bakken地区致密油藏采收率及经济效益的影响，可以有助于优化设计萨斯喀彻温省东南部致密油藏区块的开发及开采方案。

关键词: Bakken油藏, 非常规性油藏, 数值模拟, 注二氧化碳法, 水气（CO₂）交替法

Abstract: The Bakken formation is an extremely tight oil reservoir with characteristics of low porosity and permeability. In this study, a ten-well numerical simulation model was built by using the reservoir and fracture properties of middle Bakken tight formation to represent the characteristics of the Viewfield pool in southeast Saskatchewan. Pilot tests have been carried out to determine the reliability and feasibility of gas injection for improving tight oil recovery. To begin with, a history matching has been performed to verify the validity of the existing model with the actual field production data and pressure variation within the pilot area and determine the sensitivity of parameters. Meanwhile, this study has different recovery schemes such as the water flooding process, CO₂ flooding process, CO₂-water-alternating-gas (WAG) process, and methane flooding process were simulated to comparatively evaluate their respective effects on oil recovery. It was found that relative oil-water permeability (K_row) and connate water saturation (S_wcon) were the most sensitive parameters towards the cumulative oil productions. The simulation results indicated other important parameters which considerably affect the oil recovery factor are CO₂ injection rate, number of cycles, injection times and soaking time. Amidst the different injection methods, 2-year period of CO₂-WAG has the best performance in terms of oil recovery factor, which brings up the additional oil recovery factor to 5.033%. This work provides fundamental knowledge of evaluating the potential gas injection strategies and the optimum operating conditions for enhancing the recovery of southeast Saskatchewan tight oil formation.

Key words: Bakken Formations, unconventional reservoirs, numerical simulation, CO₂ flooding, CO₂-WAG

中图分类号:

TE155

邓笑函, 陈恬, 赵嘉, 贾钠. Bakken油藏注气方式的模拟与预测[J]. 西南石油大学学报(自然科学版), 2021, 43(5): 104-112.

DENG Xiaohan, CHEN Tian, ZHAO Jia, JIA Na. Simulation and Prediction of Gas Injection Strategy for the Bakken Formation in Southeast Saskatchewan[J]. Journal of Southwest Petroleum University(Science & Technology Edition), 2021, 43(5): 104-112.

0
/ / 推荐

导出引用管理器 EndNote|Ris|BibTeX

链接本文: http://journal15.magtechjournal.com/Jwk_xnzk/CN/10.11885/j.issn.1674-5086.2021.03.14.01

http://journal15.magtechjournal.com/Jwk_xnzk/CN/Y2021/V43/I5/104

参考文献

[1] ZHANG K, PERDOMO M. E, KONG B, et al. CO₂ near-miscible flooding for tight oil exploitation[C]. SPE 176826-MS, 2015. doi:10.2118/176826-MS
[2] LUO Peng, LUO Weiguo, LI Sheng. Effectiveness of miscible and immiscible gas flooding in recovering tight oil from Bakken reservoirs in Saskatchewan, Canada[J]. Fuel, 2017, 208:626-636. doi:10.1016/j.fuel.2017.07.044
[3] YU Wei, LASHGARI H R, SEPEHRNOORI K. Simulation study of CO₂ huff-n-puff process in Bakken tight oil reservoirs[C]. SPE 169575-MS, 2014. doi:10.2118/169575-MS
[4] YU Wei, LASHGARI H R, WU Kan, et al. CO₂ injection for enhanced oil recovery in Bakken tight oil reservoirs[J]. Fuel, 2015, 159:354-363. doi:10.1016/j.fuel.2015.06.092
[5] SONG Chengyao, YANG Daoyong. Experimental and numerical evaluation of CO₂ huff-n-puff processes in Bakken Formation[J]. Fuel, 2017, 190:145-162. doi:10.1016/j.fuel.2016.11.041
[6] SONG Chengyao. Development of CO₂ EOR techniques for unlocking resources in tight oil formations[D]. Regina:The University of Regina, Canada, 2013.
[7] KOHLRUSS D, MCLEOD J, NICKEL E. Well stimulation observations in the viewfield Bakken pool[R]. Saskatchewan:Ministry of Saskatchewan, Government of Saskatchewan, 2004.
[8] WANG Xiaoqi, LUO Peng, VAHAPCAN E R, et al. Assessment of CO₂ flooding potential for Bakken Formation, Saskatchewan[C]. SPE 137728-MS, 2010. doi:10.2118/137728-MS
[9] GHADERI S M, CLARKSON C R, GHANIZADEH A. Improved oil recovery in tight oil formations:Results of water injection operations and gas injection sensitivities in the Bakken Formation of Southeast Saskatchewan[C]. SPE 185030-MS, 2017. doi:10.2118/185030-MS
[10] GUI P, JIA X, CUNHA J C, et al. Economic analysis for enhanced CO₂ injection and sequestration using horizontal wells[J]. Journal of Canadian Petroleum Technology, 2008, 47(11):PETSOC-08-11-34-TN. doi:10.2118/08-11-34-TN
[11] KHAKHARIA P, MERTENS J, HUIZINGA A, et al. Online corrosion monitoring in a postcombustion CO₂ capture pilot plant and its relation to solvent degradation and ammonia emissions[J]. Industrial & Engineering Chemistry Research, 2015, 54(19):5336-5344. doi:10.1021/acs.iecr.5b00729
[12] FYTIANOS G, UCAR S, GRIMSTVEDT A, et al. Corrosion and degradation in MEA based post-combustion CO₂ capture[J]. International Journal of Greenhouse Gas Control, 2016, 46:48-56. doi:10.1016/j.ijggc.2015.12.028
[13] SAIWAN C, SUPAP T, IDEM R, et al. Part 3:Corrosion and prevention in post-combustion CO₂ capture systems[J]. Carbon Management, 2011, 2(6):659-675. doi:10.4155/cmt.11.63
[14] DAI Zhenxue, VISWANATHAN H, XIAO Ting, et al. CO₂ sequestration and enhanced oil recovery at depleted oil/gas reservoirs[J]. Energy Procedia, 2017, 114:6957-6967. doi:10.1016/j.egypro.2017.08.034
[15] BASSIOUNI Z. Theory, measurement, and interpretation of well logs[M]. Richardson, TX:Society of Petroleum Engineers, 1994.
[16] MANRIQUE E J, MUCI V E, GURFINKEL M E. EOR field experiences in carbonate reservoirs in the United States[C]. SPE 100063-MS, 2006. doi:10.2118/100063-MS
[17] BUJANOS J L S, ABUNDES A V A, RODRIGUEZ-De F L G, et al. Nitrogen injection in the Cantarell complex:Results after four years of operation[C]. SPE 97385-MS, 2005. doi:10.2118/97385-MS
[18] PERERA M S A, GAMAGE P, RATHNAWEERA T D, et al. A review of CO₂-enhanced oil recovery with a simulated sensitivity analysis[J]. Energies, 2016, 9(7):481. doi:10.3390/en9070481
[19] RAVAGNANI Gaspar A T F S, LIGERO E L, SUSLICK S B. CO₂ sequestration through enhanced oil recovery in a mature oil field[J]. Journal of Petroleum Science and Engineering, 2009, 65(3-4):129-138. doi:10.1016/j.petrol.2008.12.015
[20] WEST D R M, HARKRIDER J, BESLER M R, et al. Optimized production in the Bakken shale:South Antelope case study[C]. SPE 167168-MS. doi:10.2118/167168-MS
[21] HUANG Tuo, YANG Huaijun, LIAO Guangzhi, et al. Optimization of CO₂ flooding strategy to enhance heavy oil recovery[C]. SPE 174480-MS, 2015. doi:10.2118/174480-MS
[22] YANG Daoyong, SONG Chengyao, ZHANG Jiguo, et al. Performance evaluation of injectivity for water-alternating-CO₂ processes in tight oil formations[J]. Fuel, 2015, 139:292-300. doi:10.1016/j.fuel.2014.08.033
[23] BARSOTTI E, PIRI M, ALTHAUS S, et al. Solution gas drive in tight oil reservoirs:New insights from capillary condensation and evaporation experiments[C]. URTEC-2902677, 2018. doi:10.15530/URTEC-2018-2902677