Performance Evaluation and Plugging Characteristics of Controllable Self-Aggregating Colloidal Particle Profile Control Agent
In low permeability reservoirs, the reservoir pore throat is small and the micro heterogeneity is prominent. Conventional microsphere profile control agents generally have good injectability but poor plugging effect; however, profile control agents with good plugging effect generally have poor injectability, which makes it difficult for agent to realize deep profile control of reservoir. To solve this problem, styrene and acrylamide were used as monomers in the laboratory. Emulsion polymerization was used to prepare the Controllable Self-Aggregating Colloidal Particle (CSA), which was rich in amide group. The CSA microsphere dispersion solution with a particle diameter smaller than the pore throat diameter was injected into the reservoir to ensure that the profile control agent had good inject ability. After dispersing the CSA microsphere to the deep part of the reservoir, the CSA microspheres dispersed in static for a certain period of time will self-aggregate into large-sized particle clusters to achieve plugging of hypertonic channels. The CSA microsphere has the characteristics of low expansion and avoids shear fracture in the process of migration. It can be observed by transmission electron microscope that CSA microspheres still maintain regular and uniform spherical and core-shell heterogeneous structure after aging at 100 ºC for 35 days, and CSA microspheres have good thermal stability. The results of bottle test showed that with the increase of cation concentration, the aggregation time of CSA microspheres gradually shortened, and the influence of divalent cations was greater than that of monovalent ions. Physical simulation experiments show that CSA microspheres have good injectability, and the aggregated CSA particle clusters can produce effective plugging and migrate to the deep part of the reservoir for profile control.
[1] Yang H, Yu H G, Huang C L, et al. Potential evaluation and injection parameter optimization of CO2 flooding after waterflooding in low permeability reservoir. Fault-block Oil & Gas Field, 2015, 22(2): 240-244. doi:10.6056/dkyqt201502024.
[2] Zhang B K, Xu G R, Tie L L, et al. Optimization of technological parameters and evaluation of reservoir adaptation by water plugging and profile control: A case from Bohai SZ36-1 oilfield. Lithologic Reservoirs, 2017, 29(5): 155-161. doi:10.3969/j.issn.1673-8926.2017.05.019.
[3] Zhang F F. Characterization and evaluation of pore-throat structures in ultra-low permeability and tight sandstones and their impacts on petrophysical properties: A case study of the lower cretaceous in northern Songliao basin. Journal of Northeast Petroleum University, 2018, 42(5): 54-62. doi:10.3969/j.issn.2095-4107.2018.05.006.
[4] Ren X J, Li L L, Lu Y H, et al. Application on HV high-strength gel water plugging system. Lithologic Reservoirs, 2018, 30(5): 131-137. doi:10.12108/yxyqc.20180516.
[5] Yue X A, Hou J R, Qiu M J, et al. Evaluation on character of profile control by polymer gel particle. Petroleum Geology and recovery Efficiency, 2006, 13(2):81-84. doi:10.3969/j.issn.1009-9603.2006.02.025.
[6] Yang C C, Yue X A, Zhou D Y, et al. Performance evaluation of polymer microsphere with high temperature resistance and high salinity tolerance. Oilfield Chemistry, 2016, 33(2):254-260. doi:10.19346/j.cnki.1000-4092.2016.06.014.
[7] Chen Y H, Wang K L, Li G, et al. Plugging mechanism of large size profile control particles and deep migration performance. Lithologic Reservoirs, 2019, 31(01):162-167.
[8] Jia H, Ren Q, Pu W F, et al. Swelling mechanism investigation of microgel with double-cross-linking structures. Energy & Fuels, 2014, 28(11):6735-6744. doi: 10.1021/ef5012325
[9] Hua Z, Lin M, Dong Z, et al. Study of deep profile control and oil displacement technologies with nanoscale polymer microspheres. Journal of Colloid and Interface Science, 2014, 424:67-74. doi: 10.1016/j.jcis.2014.03.019
[10] Wang Z, Lin M Q, Gu M, et al. Zr-Induced high temperature resistance of polymer microsphere based on double crosslinked structure. Rsc Advances, 2018, 8(35):19765-19775. doi: 10.1039/C8RA02747A.
[11] Zhang L L, Xie G, Ju D F, et al. Laboratory study on micro suspension emulsion plugging agent performance. Lithologic Reservoirs, 2013, 25(6): 112-116. doi: 10.3969/j.issn.1009-8348.2011.07.004.
[12] Pu W F, Zhao S, Wang L L, et al. Investigation into the matching between the size of polymer microspheres and pore throats. Petroleum Geology and recovery Efficiency, 2018, 133(4):104-109. doi:10.13673/j.cnki.cn37-1359/te.2018.04.016.
[13] Yao C, Lei G, Li L, et al. Selectivity of pore-scale elastic microspheres as a novel profile control and oil displacement agent. Energy & Fuels, 2012, 26(8):5092-5101. doi: 10.1021/ef300689c.
[14] Yang H, Kang W, Yin X, et al. Research on matching mechanism between polymer microspheres with different storage modulus and pore throats in the reservoir. Powder Technology, 2017, 313:191-200. doi: 10.1016/j.powtec.2017.03.023.
[15] Hua Z, Lin M, Guo J, et al. Study on plugging performance of cross-linked polymer microspheres with reservoir pores. Journal of Petroleum Science and Engineering, 2013, 105:70-75. doi: 10.1016/j.petrol.2013.03.008.
[16] Ma G Y, Shen Y D, Gao R M, et al. Application properties of nano-/ micro-size acrylamide copolymer microsphere as profile control agent. Modern Chemical Industry, 2016(12):99-101-103. doi:10.16606/j.cnki.issn0253-4320.2016.12.023.
[17] Zou J, Yue X, Zhang J, et al. Self-assembled microspheres feasibility study for conformance control in high temperature and high salinity reservoirs. Arabian Journal of Geosciences, 2018, 11(9):195.doi: 10.1007/s12517-018-3544-0
[18] Almohsin A M, Bai B, Imqam A H, et al. Transport of nanogel through porous media and its resistance to water flow. SPE Improved Oil Recovery Symposium. Society of Petroleum Engineers, 2014. doi: 10.1016/j.jngse.2016.08.023.
[19] Yu Z, Li Y, Sha O, et al. Synthesis and properties of amphiprotic polyacrylamide microspheres as water shutoff and profile control. Journal of Applied Polymer Science, 2016, 133(17): 43366. doi: 10.1002/app.43366.
[20] Chen Z, Schuman T P, Geng J, et al. Water-free synthesis of temperature-sensitive polyacrylamide microgels and pore modeled oil recovery performance. Journal of Applied Polymer Science, 2017, 134(13): 44581. doi: 10.1002/app.44581.
[21] Lei G, Li L, Nasr-El-Din H A. New gel aggregates to improve sweep efficiency during waterflooding. SPE Reservoir Evaluation & Engineering, 2011, 14(1): 120-128.doi: 10.2118/129960-PA
[22] Xin C, Zhimin C, Bai Y, et al. Regular patterns generated by self-organization of ammonium-modified polymer nanospheres. Journal of Colloid & Interface Science, 2004, 269(1):79-83. doi: 10.1016/S0021-9797(03)00720-3.
[23] Ivanova B, Nikolova R, Lamsh Ö FT M, et al. Surface interaction and self-assembly of cyclodextrins with organic dyes. Journal of Inclusion Phenomena and Macrocyclic Chemistry, 2010, 67(3-4): 317-324. doi: 10.1007/s10847-009-9712-9.
[24] Kielland J. Individual activity coefficients of ions in aqueous solutions. Journal of the American Chemical Society, 1937, 59:1675-1678. doi: 10.1021/ja01288a032.
[1] Yang H, Yu H G, Huang C L, et al. Potential evaluation and injection parameter optimization of CO2 flooding after waterflooding in low permeability reservoir. Fault-block Oil & Gas Field, 2015, 22(2): 240-244. doi:10.6056/dkyqt201502024.
[2] Zhang B K, Xu G R, Tie L L, et al. Optimization of technological parameters and evaluation of reservoir adaptation by water plugging and profile control: A case from Bohai SZ36-1 oilfield. Lithologic Reservoirs, 2017, 29(5): 155-161. doi:10.3969/j.issn.1673-8926.2017.05.019.
[3] Zhang F F. Characterization and evaluation of pore-throat structures in ultra-low permeability and tight sandstones and their impacts on petrophysical properties: A case study of the lower cretaceous in northern Songliao basin. Journal of Northeast Petroleum University, 2018, 42(5): 54-62. doi:10.3969/j.issn.2095-4107.2018.05.006.
[4] Ren X J, Li L L, Lu Y H, et al. Application on HV high-strength gel water plugging system. Lithologic Reservoirs, 2018, 30(5): 131-137. doi:10.12108/yxyqc.20180516.
[5] Yue X A, Hou J R, Qiu M J, et al. Evaluation on character of profile control by polymer gel particle. Petroleum Geology and recovery Efficiency, 2006, 13(2):81-84. doi:10.3969/j.issn.1009-9603.2006.02.025.
[6] Yang C C, Yue X A, Zhou D Y, et al. Performance evaluation of polymer microsphere with high temperature resistance and high salinity tolerance. Oilfield Chemistry, 2016, 33(2):254-260. doi:10.19346/j.cnki.1000-4092.2016.06.014.
[7] Chen Y H, Wang K L, Li G, et al. Plugging mechanism of large size profile control particles and deep migration performance. Lithologic Reservoirs, 2019, 31(01):162-167.
[8] Jia H, Ren Q, Pu W F, et al. Swelling mechanism investigation of microgel with double-cross-linking structures. Energy & Fuels, 2014, 28(11):6735-6744. doi: 10.1021/ef5012325
[9] Hua Z, Lin M, Dong Z, et al. Study of deep profile control and oil displacement technologies with nanoscale polymer microspheres. Journal of Colloid and Interface Science, 2014, 424:67-74. doi: 10.1016/j.jcis.2014.03.019
[10] Wang Z, Lin M Q, Gu M, et al. Zr-Induced high temperature resistance of polymer microsphere based on double crosslinked structure. Rsc Advances, 2018, 8(35):19765-19775. doi: 10.1039/C8RA02747A.
[11] Zhang L L, Xie G, Ju D F, et al. Laboratory study on micro suspension emulsion plugging agent performance. Lithologic Reservoirs, 2013, 25(6): 112-116. doi: 10.3969/j.issn.1009-8348.2011.07.004.
[12] Pu W F, Zhao S, Wang L L, et al. Investigation into the matching between the size of polymer microspheres and pore throats. Petroleum Geology and recovery Efficiency, 2018, 133(4):104-109. doi:10.13673/j.cnki.cn37-1359/te.2018.04.016.
[13] Yao C, Lei G, Li L, et al. Selectivity of pore-scale elastic microspheres as a novel profile control and oil displacement agent. Energy & Fuels, 2012, 26(8):5092-5101. doi: 10.1021/ef300689c.
[14] Yang H, Kang W, Yin X, et al. Research on matching mechanism between polymer microspheres with different storage modulus and pore throats in the reservoir. Powder Technology, 2017, 313:191-200. doi: 10.1016/j.powtec.2017.03.023.
[15] Hua Z, Lin M, Guo J, et al. Study on plugging performance of cross-linked polymer microspheres with reservoir pores. Journal of Petroleum Science and Engineering, 2013, 105:70-75. doi: 10.1016/j.petrol.2013.03.008.
[16] Ma G Y, Shen Y D, Gao R M, et al. Application properties of nano-/ micro-size acrylamide copolymer microsphere as profile control agent. Modern Chemical Industry, 2016(12):99-101-103. doi:10.16606/j.cnki.issn0253-4320.2016.12.023.
[17] Zou J, Yue X, Zhang J, et al. Self-assembled microspheres feasibility study for conformance control in high temperature and high salinity reservoirs. Arabian Journal of Geosciences, 2018, 11(9):195.doi: 10.1007/s12517-018-3544-0
[18] Almohsin A M, Bai B, Imqam A H, et al. Transport of nanogel through porous media and its resistance to water flow. SPE Improved Oil Recovery Symposium. Society of Petroleum Engineers, 2014. doi: 10.1016/j.jngse.2016.08.023.
[19] Yu Z, Li Y, Sha O, et al. Synthesis and properties of amphiprotic polyacrylamide microspheres as water shutoff and profile control. Journal of Applied Polymer Science, 2016, 133(17): 43366. doi: 10.1002/app.43366.
[20] Chen Z, Schuman T P, Geng J, et al. Water-free synthesis of temperature-sensitive polyacrylamide microgels and pore modeled oil recovery performance. Journal of Applied Polymer Science, 2017, 134(13): 44581. doi: 10.1002/app.44581.
[21] Lei G, Li L, Nasr-El-Din H A. New gel aggregates to improve sweep efficiency during waterflooding. SPE Reservoir Evaluation & Engineering, 2011, 14(1): 120-128.doi: 10.2118/129960-PA
[22] Xin C, Zhimin C, Bai Y, et al. Regular patterns generated by self-organization of ammonium-modified polymer nanospheres. Journal of Colloid & Interface Science, 2004, 269(1):79-83. doi: 10.1016/S0021-9797(03)00720-3.
[23] Ivanova B, Nikolova R, Lamsh Ö FT M, et al. Surface interaction and self-assembly of cyclodextrins with organic dyes. Journal of Inclusion Phenomena and Macrocyclic Chemistry, 2010, 67(3-4): 317-324. doi: 10.1007/s10847-009-9712-9.
[24] Kielland J. Individual activity coefficients of ions in aqueous solutions. Journal of the American Chemical Society, 1937, 59:1675-1678. doi: 10.1021/ja01288a032.
@article{"International Journal of Electrical, Electronic and Communication Sciences:80762", author = "Zhiguo Yang and Xiangan Yue and Minglu Shao and Yang Yue and Tianqi Yue", title = "Performance Evaluation and Plugging Characteristics of Controllable Self-Aggregating Colloidal Particle Profile Control Agent", abstract = "In low permeability reservoirs, the reservoir pore throat is small and the micro heterogeneity is prominent. Conventional microsphere profile control agents generally have good injectability but poor plugging effect; however, profile control agents with good plugging effect generally have poor injectability, which makes it difficult for agent to realize deep profile control of reservoir. To solve this problem, styrene and acrylamide were used as monomers in the laboratory. Emulsion polymerization was used to prepare the Controllable Self-Aggregating Colloidal Particle (CSA), which was rich in amide group. The CSA microsphere dispersion solution with a particle diameter smaller than the pore throat diameter was injected into the reservoir to ensure that the profile control agent had good inject ability. After dispersing the CSA microsphere to the deep part of the reservoir, the CSA microspheres dispersed in static for a certain period of time will self-aggregate into large-sized particle clusters to achieve plugging of hypertonic channels. The CSA microsphere has the characteristics of low expansion and avoids shear fracture in the process of migration. It can be observed by transmission electron microscope that CSA microspheres still maintain regular and uniform spherical and core-shell heterogeneous structure after aging at 100 ºC for 35 days, and CSA microspheres have good thermal stability. The results of bottle test showed that with the increase of cation concentration, the aggregation time of CSA microspheres gradually shortened, and the influence of divalent cations was greater than that of monovalent ions. Physical simulation experiments show that CSA microspheres have good injectability, and the aggregated CSA particle clusters can produce effective plugging and migrate to the deep part of the reservoir for profile control.", keywords = "Heterogeneous reservoir, deep profile control, emulsion polymerization, colloidal particles, plugging characteristic.", volume = "16", number = "4", pages = "54-6", }
