COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
·
2025
·
IF 5.4
Yun Cheng,Miaomiao Hu,Jie Cao,Long Zang,Pengpeng Li,Hang Zhang,Qinglu Chang,Jintang Guo
Preformed particle gels (PPGs) have extensive application potential for reducing excess water content in reservoirs due to their adaptability, stability, and deformability. However, the mechanical properties of conventional PPGs are poor, and the swollen particles are susceptible to damage when passing through formation fractures. In this paper, a novel methacrylated crosslinking agent (ChMA) was prepared and cross-linked with functional monomers to form the first hydrogel network, and then the ChMA crosslinking based double network structure hydrogels (CBDCH) were prepared by stepwise modification via tannic acid (TA). TA forms hydrogen bonds with amino, carboxyl, or sulfonic groups in the hydrogel through its phenolic hydroxyl groups, thereby promoting the formation of a physical crosslinked network. The CBDCH with double network structure exhibited excellent rheological and mechanical properties, including excellent elastic modulus (12,041 Pa), high strength (0.124 MPa) and high toughness (1.63 MJ m −3 ). In addition, the thermal stability of CBCH and CBDCH hydrogels were tested at different temperatures and salinities. The results showed that the CBDCH hydrogel has excellent thermal stability and better swelling properties at high temperature and high salt (10.29 at 120 °C). A core drive test was conducted on naturally fractured cores, and the results indicated that at a water injection flow rate of 0.5 mL/min, the breakthrough pressure of CBDCH was 180 psi/ft, demonstrating a significant blocking effect that meets the fundamental standards for water plugging in oilfields. This study highlights the potential of incorporating a dual network structure into PPGs to develop tough, temperature-resistant, and salt-resistant water-plugging materials.
研究领域:
材料科学
·
石油工程
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产品关联
DOI
高影响因子
ACS Applied Materials & Interfaces
·
2023
·
IF 9.5
Hongjie Chen,Peng Wei,Ying Qi,Yahong Xie,Xueli Huang
Hydrogels have been widely applied to the water shutoff in oilfields due to their excellent three-dimensional network and thermal and physicochemical stability, and it is still a huge challenge to develop new hydrogels with simple preparation, low cost, and high mechanical performance that can meet the requirements of practical applications. Herein, we devised a simple and universal manufacturing method for regulating the hydrogen bonds between poly(vinyl alcohol) (PVA) and cellulose nanofibers (CNF) via the water-diffusion action, thus fabricating a physically tough PVA–CNF hydrogel for the in situ water shutoff. This method allowed the polymer chains to strengthen the molecular interactions between polymers upon replacing with water (a poor solvent) to regulate the cross-linking structure, characterizing by the nano-crystallinity domains and fibrillar segments, which also accounted for the thermal stability, extraordinary elasticity, high stretchability, and toughness of PVA–CNF hydrogel. Further, the obtained PVA–CNF hydrogel exhibited superb plugging performance, that is, the breakthrough pressure gradient could reach 71.56 MPa·m–1, surpassing all currently reported gelling water shutoff agents. This water-induced in situ hydrogelation made it well suited as a water shutoff agent in oilfields and may provide a promising strategy to fabricate mechanically robust smart materials for the water shutoff projects with low cost, simple processing, and high efficiency.
研究领域:
材料科学
·
石油工程
✓ 已验证
产品关联
DOI
PubMed
高影响因子
JOURNAL OF INDUSTRIAL AND ENGINEERING CHEMISTRY
·
2022
·
IF 6.76
Jintao Li,Peng Wei,Yahong Xie,Ziteng Liu,Hongjie Chen,Long He
Hydrogels have been widely adopted for in-depth water control in mature oilfields, however, the poor mechanical properties limit their application. Herein, a conjoined-network induced hydrogel was prepared through the in-situ free radical copolymerization of acrylamide (AM), Acrylic acid (AA) and N,N′-methylenebis(acrylamide) (MBA) in the presence of nano-cellulose (CNF/ACNF), and the coordination effect between aluminium ion and carboxyl. The results showed that a small amount of nano-cellulose (0.2 %) increased the compressive strength of the hydrogel by 7 times. The presence of nano-cellulose endowed the hydrogel with excellent thermal stability and high shearing elasticity, at the same time, could effectively reduced the swelling rate that hindered its disintegration in practical application. The evaluation of sand-pack plugging suggested that the double cross-linked nano-cellulose hydrogel presented a significant capacity for efficient water plugging, where the breakthrough pressure gradient was as high as 23.73 MPa, the plugging rate reached 99.9%, and the maximum residual resistance factor was 3902.06. This work provided a novel design of hydrogel with high compressive strength and satisfactory stability for water shutoff and conformance control in heterogeneous oil reservoirs.
研究领域:
材料科学
·
石油工程
✓ 已验证
DOI
高影响因子
Gels
·
2025
·Vol. 11
·期 4
·305
·
IF 5.3
Shuanghu Si,Yifei Liu,Yinghui Jiang,Chenwei Zou,Ning Yang,Dongfang Lv,Xizhuo Miao,Caili Dai
In fractured reservoirs, fractures serve as both water channeling and oil flow channels. Because of the impact of bottom water coning, the water channeling phenomenon becomes more problematic in the middle and late stages of reservoir development. Furthermore, residual oil is limited to small-scale fractures. In multi-scale fractures, the conventional pressure-bearing pattern of plugging agents is ambiguous. This results in low oil recovery, low sweep efficiency from water flooding, and low plugging agent application efficiency. Until now, the pressure-bearing patterns related to gel strength in multi-scale fractures have not been clear. In this paper, the gelation performances of temperature-resistant gel (TRG) samples with different elastic moduli were investigated. The elastic modulus of the TRG was normalized by the elastic modulus (G′) and viscosity modulus (G″). Subsequently, we carried out research on the bottom water pressure patterns of TRGs. This study revealed the pressure-bearing patterns of the TRGs under multi-scale fractures. A corresponding influence pattern chart was established, and the optimal surface function was fitted using the MATLAB nonlinear surface data fitting method. Finally, an application experiment for the characteristic chart was carried out. The plugging rate was evaluated based on the permeability reduction and pressure differential across the core samples before and after gel injection. Subsequently, a TRG with certain elastic moduli before and after plugging the core fracture node was selected from the chart. The elastic modulus of the TRG at the injection node prior to plugging was 14.29 Pa. The elastic modulus of the TRG at the injection node after plugging was 19.42 Pa. The experimental results showed that the TRG with an elastic modulus of 19.42 Pa effectively plugged the fractures and remained stable for over 90 days under a pressure differential of 53 KPa, resulting in a 58.7% improvement in oil recovery compared with water flooding. However, it was difficult for the TRG with an elastic modulus of 14.29 Pa to plug fractures efficiently, and it only enhanced the oil recovery by 15.2%. The primary aim of this work was to establish a quantitative and normalized evaluation method for temperature-resistant gels (TRGs) used in fractured reservoirs. By introducing a classification system based on the elastic modulus (G′) and correlating it with the fracture scale and plugging performance, this study bridges the gap between laboratory gel evaluations and field applications. The results provide practical design criteria and contribute to improving the efficiency and adaptability of gel plugging strategies under harsh reservoir conditions.
研究领域:
石油工程
·
地质学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
Processes
·
2022
·Vol. 10
·期 10
·1904
·
IF 3.352
Panyang Guo,Yongle Ma,Houshun Jiang,Jie Wang,Hualei Xu
In the development of natural gas reservoirs, the water produced in wells will cause a decline in gas well productivity. In this study, a selective frozen gel plugging agent system suitable for water plugging in gas reservoirs under conditions of high temperature and high salinity. The plugging capacity of the gel system was evaluated. The experimental results showed that: (1) the optimal experimental scheme of the frozen gelling system was as follows: 107 °C with 1.0% AM-AMPS +0.6% p-benzenediol +0.6% hexamethylenetetramine +0.2% thiourea. (2) The optimal injection volume of the system for water phase plugging was 0.5 PV, and the system has an excellent plugging effect at a permeability of 356–3118 mD. (3) The system could also effectively improve the degree of heterogeneity, and the smaller the degree of heterogeneity, the better the improvement effect. (4) The gel system had a good effect on different plugging methods, and the gas medium did not affect the plugging performance. This study provides a sufficient theoretical basis for the exploitation of high-temperature and high-salinity water-bearing gas reservoirs through experimental research, which is of great significance for improving production capacity.Keywords:high temperature and high salinity;water-bearing gas reservoir;selective water shutoff agent;permeability;plugging property
研究领域:
石油工程
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
ACS Applied Polymer Materials
·
2025
·
IF 4.7
Yan Xue,Honghai Long,Hong Xu,Xunyu Zhang,Bing Wei,Jun Lu
Gel treatment is a highly effective technique for conformance control, significantly managing water production and enhancing oil recovery in mature reservoirs. However, the performance of conventional hydrogel systems often deteriorates under harsh conditions such as elevated temperatures and high salinity. To overcome this limitation, we developed a hydrogel with exceptional stretchability and resilience by integrating phenyl nanospheres (PNSs) as nanocross-linkers within polyampholyte chains. The PNSs were synthesized through precipitation polymerization of divinylbenzene in a water/ethanol solvent. P(AM-AMP-DAD)PNS gels were fabricated by copolymerizing acrylamide (AM) with equimolar amounts of 2-acrylamido-2-methylpropanesulfonate sodium (AMPS-Na) and diallyl dimethylammonium chloride (DADMAC), utilizing PNSs as cross-linkers. This unique structure achieved a remarkable breaking elongation of 920% at 100 kPa and exhibited no fractures after five cycles at 400% strain. Hydrophobic interactions among PNSs created dynamic association domains, enabling reversible energy dissipation and improving mechanical robustness. The antipolyelectrolyte effect of the polyampholyte chains provided exceptional fracture resistance in ultrahigh-salinity environments. The swelling ratio of P(AM-AMP-DAD)PNS gels remained stable and even slightly increased in formation water, particularly at 130 °C, where it was 1.2 times higher than at room temperature. Furthermore, this hydrogel demonstrated long-term stability under extreme conditions (130 °C, 2.2 × 105 mg L–1 salinity, Ca2+ + Mg2+ = 1.3 × 104 mg·L–1) for up to 60 days. Core-flooding tests revealed that the fractured core, treated with P(AM-AMP-DAD)PNS particles and subjected to high-temperature aging, achieved a breakthrough pressure exceeding 6 MPa, with a plugging efficiency of 99.93%. These results confirm the hydrogel’s superior plugging performance under ultraharsh reservoir conditions, making it a promising candidate for enhanced oil recovery applications.
研究领域:
材料科学
·
石油工程
✓ 已验证
产品关联
DOI
高影响因子
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
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2020
·
IF 3.99
Mengjing Cao,Qiang Cai,Guangfan Guo,Jinyao Yang,Dong Chen
Magnetic composite polymeric microspheres have several technical advantages in improving oil recovery applications. Swelling and stability are key properties that are a direct result of water shutoff efficacy. However, the important aspect of swelling and stability is the materials of the microspheres. In this paper, multiple–shell structures of magnetic hybrid composite spherical particles with different materials which were Fe 3 O 4 @SiO 2 @PAM, Fe 3 O 4 @TiO 2 @PAM, Fe 3 O 4 @SiO 2 @PAM-MBAAm were synthesized via a combination method and theirs physical properties including morphology, particle size distribution, and water swelling property were thoroughly examined. Meanwhile, the plugging performances were studied. The main goal of this paper was to investigate effect of materials of constituents on swelling properties of microspheres. The results demonstrate that both inorganic and organic constituents can affect the swelling properties of microspheres. Moreover, plugging properties of microspheres with different components are different at different salt concentrations, temperatures and pH values. Meanwhile, the results also open up possibilities for studying on the system of heat-resistant, salt-resistant, and pH-resistant oil displacement agent.
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
ACS Omega
·
2023
·
IF 4.1
Hongda Hao,Jiaxin Li,Song Deng,Bihua Xian,Zheng Tang,Shuo Yang,Jirui Hou
The high-temperature reservoir (105 °C) in the Liubei block of Jidong Oilfield, with severe longitudinal heterogeneity, has entered a high water-cut stage. After a preliminary profile control, the water management of the oilfield still faces serious water channeling problems. To strengthen water management, N2 foam flooding combined with gel plugging for enhanced oil recovery was studied. In this work, considering a high-temperature reservoir of 105 °C, a composite foam system and starch graft gel system with high temperature resistance were screened out, and displacement experiments in one-dimensional heterogeneous cores were carried out. Through the three-dimensional experimental model and numerical model of a 5-spot well pattern, physical experiments and numerical simulations were carried out respectively to study water control and oil increase. The experimental results showed that the foam composite system had good temperature resistance up to 140 °C and oil resistance up to 50% oil saturation and was helpful to adjust the heterogeneous profile in a high temperature of 105 °C. The starch graft gel system had good injection performance, with a solution viscosity of 18.15 mPa·s, and its gel strength could effectively seal the high-permeability layer, with a gel viscosity of 34950.92 mPa·s. The displacement test results showed that after a preliminary implementation of N2 foam flooding, N2 foam flooding combined with gel plugging could still improve oil recovery by 5.26%. Compared with preliminary N2 foam flooding, gel plugging could control the water channeling in the high-permeability zone near the production wells. The combination of foam and gel made N2 foam flooding and subsequent waterflooding divert to flow mainly along the low-permeability layer, which was conducive to enhance water management and improve oil recovery. This method can be used as an effective technology to manage similar heterogeneous reservoirs.
研究领域:
石油工程
·
化学工程
✓ 已验证
产品关联
DOI
PubMed
高影响因子
POLYMER COMPOSITES
·
2016
·Vol. 39
·期 2
·368-376
·
IF 2.004
Tian-Hong Zhao,Ji-Yue Xing,Wan-Fen Pu,Zhi-Ming Dong,Cheng-Dong Yuan,Guo-Feng Peng,Fa-Yang Jin,Ji-Jia Xia
Polyacrylamide-montmorillonite organic-inorganic composites (poly[AM/O-MMT]) were synthesized by copolymerization of acrylamide (AM) on organic modified montmorillonite (O-MMT) using N , N -methylene-bis-acrylamide (MBA) as a crosslinker and ammonium persulfate (APS) as an initiator in an aqueous solution. The montmorillonite (MMT) was modified by methacryloyloxy ethyl dimethyl hexadecyl ammonium bromide (DMB) which was synthesized by 2-(dimethylamino) ethyl methacrylate with 1-bromohexadecane. The FTIR and XRD were used to verify the organification of MMT with DMB. The effects of the amount of the DMB and O-MMT on water absorption were studied. The swelling behavior in different saline solution and re-swelling ability in distilled water were investigated. The results showed that DMB and O-MMT content have an important effect on the water absorption of the composites. The addition of the DMB enhanced the salt resistance and delayed the swelling speed of the poly(AM/O-MMT). Simultaneously, the toughness was measured. The water blocking and profile control ability were evaluated by core physical simulation experiments. The results indicated that the poly(AM/O-MMT) has good plugging ability and profile control ability. The properties tested indicated that the poly(AM/O-MMT) has a promising prospect to be applied as a profile control or water shut-off agent for enhanced oil recovery in high salinity reservoirs. POLYM. COMPOS., 39:368–376, 2018. © 2016 Society of Plastics Engineers
研究领域:
石油工程
·
材料科学
·
化学工程
✓ 已验证
DOI
高影响因子
ENERGY & FUELS
·
2020
·
IF 3.421
Dexin Liu,Ruihao Zhang,Xuewei Liu,Weiyu Chen,Xuyang Tian,Jie Yuan,Bo Huang
A two-step solution immersion method was used to successfully fabricate a superhydrophobic film on the surface of the core, which can effectively separate oil and water. The optimal reagent concentration of the superhydrophobic surface was 1.0 wt % aminopropyl triethoxysilane + 0.7 wt % stearoyl chloride + 0.2 wt % triethylamine, suitable for reservoirs with a formation temperature around 40–100 °C, and the maximum contact angle of the prepared superhydrophobic surface was 155° with a sliding angle smaller than 3°. A scanning electron microscope and a contact angle measuring instrument were used to characterize the surface. Displacement experiments and oil–water separation experiments demonstrated that the superhydrophobic surface could significantly change the wettability of the formation and have a good selective water shut-off performance. The presented method is rapid and convenient and thus should be of significant value for the industrial fabrication of the superhydrophobic surface and should have a promising future in selective water shut-off in oilfields.
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
JOURNAL OF MOLECULAR LIQUIDS
·
2024
·
IF 5.3
Kailu Wang,Yaqi Guo,Jie Wen,Huan Yang,Hui Zhang
Polymer gel technology has been proven to be one of the most effective methods for conformance control and enhanced oil recovery. However, to effectively gel highly permeable layers, precise placement of the gelant within the formation is required. Herein, to make the most use of polymer gel in conformance control, a novel magnetic smart polymer gel consisting of polyacrylamide and Fe 3 O 4 @polyethylenimine, is designed and prepared as a conformance fluid to achieve directional plugging in target reservoirs. To deeper understanding of the properties of Fe 3 O 4 @polyethylenimine and smart gel, as well as how they are formed and function, the microstructure of these materials was characterized through various techniques, including analysis of their crystal and chemical structures, micromorphology, and cross-linking mechanism, et al. The rheological tests suggest that the system has good viscosity and elasticity, and the gel strength can reach 105,463 mPa⋅s after aging 30 days at 120 °C. Furthermore, the controlled manipulation indicated that smart gel can move quickly and repeatedly to a designated location under a magnetic field. Additionally, the influence of the magnetic generator on the intelligent plugging performance of the smart gel system is also explored. It has been found that magnetic plugging can extend the effective lifespan of smart gel. Finally, the conformance control performance of the smart gel system is revealed by the parallel cores flow experiment. This work presents a novel smart gel system designed for directional plugging, to enhance conformance control in high-temperature oil reservoirs.
研究领域:
石油工程
·
材料科学
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
BMC Chemistry
·
2025
·
IF 4.6
Qiming Zheng,Chenming Peng,Wei Qian,Xin Wang,Defeng Wang,Kairui Yang
This investigation developed and evaluated a new type of high-temperature-resistant gel particle system (DPAG), which is specifically designed for conformance control in high-temperature reservoirs. Conventional conformance control systems, including polymer gel systems and foam-based technologies, often suffer from thermal degradation and insufficient plugging stability under high-temperature environments. To address these limitations, DPAG gel particles were synthesized via inverse emulsion polymerization, incorporating thermally stable functional monomers (AMPS and DAC) to create a dual-crosslinking network combining covalent bonds and electrostatic interactions. A comprehensive characterization combining chemical structure assessment, particle size measurement and microscopic morphology examination confirmed the successful synthesis of DPAG gel particles, revealing their uniform size distribution and well-defined morphology. Thermodynamic stability analysis, combined with rheological characterization, revealed that DPAG gel particles exhibit enhanced structural integrity, thermal resistance, and mechanical strength compared to conventional AM gel particles. Swelling kinetic studies revealed that DPAG gel particles exhibit significantly enhanced swelling characteristics, achieved a swelling ratio of 14.6. Experimental results indicated that DPAG microsphere dispersions at concentrations of 0.1% to 0.5% not only maintained excellent injectivity but also achieved remarkable plugging efficiency, reaching up to 98.7%. Particularly under high-temperature conditions, DPAG gel particles displayed outstanding stability, retaining excellent mechanical properties after 30 days with less than 17.4% strength loss. Core flooding experiments demonstrated that DPAG gel particles exhibit both deep migration capability and long-term stability in high-temperature reservoirs, ultimately enhancing oil recovery by 22.4%. These findings strongly indicate the significant potential of DPAG gel particles for well conformance control in high-temperature oilfields.
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产品关联
DOI
PubMed
高影响因子
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