Geoenergy Science and Engineering
·
2024
·
IF 0
Tiantian Zhang,Mingwei Gao,Zhiwen Li,Xiaoyong Wen,Zhiping Li,Lan Wang,Caspar Daniel Adenutsi,Qianru Yang,Qing You
Nanoparticles have been proven to be potential additives for hydraulic fracturing fluid. However, the application of nanoparticle-enhanced fracturing fluid systems in offshore low-permeability reservoirs are limited, and the mechanism by which the corresponding gel breaking fluid enhances oil recovery (EOR) is unclear. In this work, a SiO 2 -enhanced seawater-based viscoelastic surfactant (VES) fracturing fluid system was initially prepared, and the imbibition influencing factors of the SiO 2 -enhanced gel breaking fluid were systematically investigated. Subsequently, the imbibition mechanism by SiO 2 -enhanced gel breaking fluid was explored through examining its synergistic effect on interface properties and the distribution laws of oil-water phases in micropores during the imbibition process. The results showed that proposed system could maintained stability for more than 6 months, and exhibited rheological performance, yielding an increase 26% in temperature/shear resistance. Moreover, the corresponding gel breaking fluid performed an exceptional capacity for imbibition oil production, the oil recovery was increased by 7.92% compared to the conventional gel breaking fluid system and the imbibition time was extended from 30 h to 70 h. The synergistic adsorption of nano-SiO 2 and surfactants on the interface was responsible for wettability alteration and interfacial tension (IFT) reduction. Imbibition primarily occurred in mesopores, nano-SiO 2 reduced the flow resistance of oil-water two phases in pores, and the residual oil within the pores was exceedingly mobilized. This work provides foundation research of application of SiO 2 -enhanced seawater-based VES fracturing fluid in offshore low permeability reservoirs.
研究领域:
石油工程
·
材料科学
✓ 已验证
DOI
MOLECULES
·
2024
·Vol. 29
·期 11
·2596
·
IF 4.2
Guohui Qu,Bowen Li,Yikun Liu,Zilu Zhang,Lifeng Bo,Jiqiang Zhi,Xuebin Tian,Xiaorui Bai,Xiunan Li,Qi Lv
Polymer microspheres with temperature and salt resistance were synthesized using the anti-suspension polymerization method, incorporating the functional monomers AMPS, AM, and AA. To enhance their self-gelling properties, the microspheres were designed with a core–shell structure. The shell is composed of a polymeric surfactant, fatty alcohol polyoxyethylene ether methacrylate (AEOMA), which serves as a thermosensitive crosslinking agent, enabling self-crosslinking upon shell decomposition, addressing compatibility with reservoir pore throat dimensions. Comprehensive characterizations including infrared spectroscopy, scanning electron microscopy, optical microscopy, and laser particle size analysis were conducted. The microspheres exhibited successful synthesis, a nanoscale size, and regular spherical morphology. They demonstrated excellent temperature and salt resistance, making them suitable for high-temperature, high-salinity reservoir profile control. With a stable three-dimensional network structure, the microspheres displayed good expansion behavior due to hydrophilic groups along the polymer chains, resulting in favorable water affinity. Even after aging, the microspheres maintained their gelling state with a distinct and stable microscopic network skeleton. They exhibited superior plugging performance in low-permeability reservoirs, while effectively improving water absorption profiles in reservoirs with permeability contrasts of 10 to 80, thereby enhancing oil recovery.
研究领域:
石油工程
·
高分子材料
·
油田化学
·
提高采收率
✓ 已验证
DOI
高影响因子
JOURNAL OF MOLECULAR LIQUIDS
·
2025
·
IF 5.2
Xiujun Wang,Zhe Sun,Jian Zhang,Shenwen Fang,Jiaqi Huang
Polymer microspheres have been used in the field of heterogeneous reservoir profile control, but their temperature and salt resistance still need to be improved. In this paper, N’N-dimethylacrylamide (DMA) and sodium styrene sulfonate (NaSS) were used as monomers, divinylbenzene (DVB) was used as cross-linker, and inverse emulsion polymerization was adopted to preparation the ultra-high temperature resistant polymer microsphere. After the investigation of the influences of emulsification shear time, monomer concentration, mass ratio of DMA to NaSS, and DVB addition on the polymerization result, a kind of polymer microspheres (PNS microspheres) that could maintain long-term stability in different brines (including seawater) at 150 °C for 45 days was prepared. The temperature and salt resistance of PNS microspheres are significantly better than that of polyacrylamide microspheres. The size of PNS microspheres is about 30 μm, and they can expand by about 2–4 times in low salinity brine at 150 °C, while they do not expand in seawater. Plugging effect experiment results showed that PNS microspheres can achieve a plugging rate of over 90 % for porous media with a water permeability ≤ 600 mD. T 2 spectrum of PNS microsphere displacement effect presented that it can effectively block the large pore throats and achieve micro fluid flow diversion, while oil displacement effect showed it can improve oil recovery of about 20 %. This work provides a viable candidate material expected to be applied for profile control in offshore high-temperature heterogeneous reservoirs.
研究领域:
石油工程
·
材料科学
✓ 已验证
产品关联
DOI
高影响因子
MOLECULES
·
2025
·Vol. 30
·期 7
·1537
·
IF 4.6
Zhaozheng Song,Shiyuan Xia,Tongji Yang,Zhihong Li,Jiayi Li
To investigate the specific performance enhancement of oilfield surfactants by using sodium p-aminobenzenesulfonate as a connecting group, cationic surfactant N,N-dimethyl-N-(oxiran-2-ylmethyl)dodecan-1-aminium (DDPA) and zwitterionic gemini surfactant sodium 4-[bis(3-(dodecyldimethylamino)-2-hydroxypropyl)amino]benzenesulfonate (DDBS) were synthesized. The oil recovery performance of these surfactants was compared, revealing that DDBS outperforms DDPA in thermal stability, wettability, adsorption, and resistance to temperature and salinity variations, as well as surface/interface activity, except for emulsification. Core flooding experiments, simulating the conditions of the Xinjiang oilfield, demonstrated that DDBS can achieve the same enhanced oil recovery effect at a concentration that is 1/15 of that of DDPA. Compared with water, DDBS and DDPA can incrementally enhance recovery rates by 7.9% and 8.5%. Furthermore, the synergistic formulation of DDBS with sodium dodecylbenzenesulfonate (SDS) significantly optimized performance, achieving a reduction in interfacial tension to 0.0301 mN m−1. This study provides a research and data foundation for the application of new surfactants in petroleum extraction.
研究领域:
石油工程
·
化学工程
·
表面科学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
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