JOURNAL OF APPLIED POLYMER SCIENCE
·
2022
·Vol. 140
·期 3
·e53338
·
IF 3.057
Shenglong Shi,Jinsheng Sun,Kaihe Lv,Qingzhi Wen,Yingrui Bai,Jintang Wang,Jiafeng Jin,Jingping Liu,Xianbin Huang,Jian Li
To prepare the thickener of fracturing fluid with temperature resistance, salt resistance and quick dissolution, an emulsion thickener (ASC) was synthesized by acrylamide, acrylic acid, 2-acrylamide-2-methylpropanesulfonic acid, and acryloyl morpholine. The dissolution, salt resistance and drag reduction of ASC, and the viscoelasticity, temperature resistance and shear resistance and gel breaking properties of fracturing fluid formed by ASC and zirconium crosslinker were investigated. The results showed that the sticky time of ASC was less than 60 s and the drag reduction rate was 72.5% in 100,000 mg/L brine, showing that ASC had thickening ability in high salinity brine and satisfied the requirements of continuous fluid preparation on the fracturing process. The viscosity of ASC fracturing fluid was 98 mPa s after shearing at 200°C and 170 s −1 for 150 min when the salinity was 100,000 mg/L. When the ammonium persulfate concentration was 400 mg/L, the viscosity of the broken fluid was 4.0 mPa s. The temperature resistance, salt resistance and shear resistance of ASC emulsion fracturing fluid could be significantly improved by the introduction of acryloyl morpholine, ASC fracturing fluid had the characteristics of high elasticity and low viscosity, which could meet the application requirements under ultra-high temperature reservoirs.
研究领域:
石油工程
·
高分子化学
✓ 已验证
产品关联
DOI
高影响因子
COLLOID AND POLYMER SCIENCE
·
2025
·
IF 2.3
Liu Yinyin,Wang Lei,Liu Guiru,Jin Hongtao,Lai Xiaojuan,Li Haibin,Chen Jiali
X-β-cyclodextrin (β-CD), a vinyl-functionalized monomer, was successfully synthesized through the chemical modification of β-CD. Subsequently, X-β-CD was co-polymerized with acrylic acid, acrylamide, and 2-acrylamido-2-methylpropane sulfonic acid via free radical copolymerization to produce a novel hydrophobic inclusion polymer—X-β-HPAM. The structure of X-β-HPAM was characterized using Fourier transform infrared spectroscopy, proton nuclear magnetic resonance spectroscopy, and scanning electron microscopy. Furthermore, its aqueous rheological properties were analyzed through rheometry. The results revealed that at shearing temperatures of 120 °C and 150 °C and a shear rate of 170 s −1 , the viscosity of a 0.4% X-β-HPAM aqueous solution gradually increased beyond a shear time of 1200 s, indicating the thickening effect of the X-β-CD monomer on the solution at elevated temperatures. Following shearing for 2 h, the residual viscosity stabilized at 62.24 mPa·s, after undergoing a shearing process for a duration of 2 h, the viscosity of a X-β-HPAM salt solution, with a mass fraction of 0.4% and dissolved in a 5% NaCl aqueous solution at a temperature of 150℃, remains consistently stable at the value of 60.04 mPa·s, demonstrating the excellent salt, temperature, and shear resistance of X-β-HPAM. Thus, β-CD-modified polyacrylamide enhances the thermal resistance and shear resistance of fracturing fluids, thereby improving recovery efficiency. Graphical abstract
研究领域:
材料科学
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
·
2024
·
IF 4.9
Tiantian Zhang,Xiangchun Chang,Xiaoyong Wen,Zhiwen Li,Qianru Yang,Zhiping Li,Caspar Daniel Adenutsi,Mingwei Gao,Qing You
Hydraulic fracturing has been proposed as a potential technology for the development of low-permeability oil reservoirs and also has promising application prospects offshore. In this study, a novel SiO 2 -enhanced seawater-based temperature-resistant clean fracturing fluid was formulated. The fracturing fluid main agents, additives and reducing agents were screened. Besides, the physical and chemical properties (rheology) as well as application (i.e., sand-carrying, gel-breaking, dynamic fluid loss, dynamic damage and anti-swelling) performance of the proposed SiO 2 -enhanced seawater-based temperature-resistant clean fracturing fluid were systematically investigated. It was revealed that 3.2 wt% AASB-17+1.92 wt% NaSal+0.1 wt% SC-107+0.1 wt% TS3 was the optimal SiO 2 -enhanced seawater-based clean fracturing fluid system formula. The SiO 2 -enhanced seawater-based temperature-resistant clean fracturing fluid exhibited remarkable rheological characteristics , the temperature and shear resistance was increased by 28 %, with a maximum temperature resistance of 90ºC. This system can be applied to the fracturing development of most oil reservoirs in the Bohai Bay. In addition, the presence of SiO 2 nanoparticles significantly improved the sand-carrying properties of the proposed clean fractuirng fluid system. The experimental results also suggested that the SiO 2 -enhanced seawater-based temperature-resistant clean fracturing fluid showed excellent performance of shear recovery (fixed shear viscosity recovery rate was 100 %), gel breaking (30 min,1 mPa·s), filter loss ( C w =4.75×10 −4 m/min 1/2 ), anti-swelling (anti-swelling rate was 77.78 %) and salt tolerance. This study provides fundamental technical support for the application of SiO 2 -enhanced seawater-based temperature-resistant clean fracturing fluid in offshore fracturing.
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
·
2023
·Vol. 28
·期 7
·3125
·
IF 4.6
Jiqiang Zhi,Yikun Liu,Jinfeng Chen,Lifeng Bo,Guohui Qu,Nan Jiang,Weizhong He
We targeted high-temperature and highly saline old oil fields, whose environmental conditions could be attributed to the significantly high heterogeneity cause by long-term water flooding. The Huabei Oilfield was chosen as the research object. We developed a hydrophobic functional monomer–polymer with temperature and salt resistance by introducing the temperature-resistant and salt-resistant monomer NVP and a hydrophobic functional monomer into the main chain for copolymerization. We used a crosslinking agent with phenolic resin to prepare a weak gel system that showed temperature and salt resistance and investigated its temperature and salt resistance, infective property, plugging performance, liquid flow ability, micropore throat migration, and plugging characteristics. The results obtained using the infrared spectroscopy technique revealed the successful preparation of the phenolic resin crosslinker. The weak gel exhibited good temperature and salt resistance when the polymer concentration was 2000 mg/L, the cohesion ratio was 1:1.5, the additive concentration was 2000 mg/L, the reservoir temperature was 120 °C, and the injected water salinity was 40,300.86 mg/L. The average viscosity retention rate of the 90-day weak gel reached more than 80% and its microstructure was examined. The coreflow experiment results revealed that the weak gel system was characterized by good infectivity. After plugging the weak gel, the effect on the direction of the liquid flow was evident and the flow rate of the low permeability layer increased to a maximum of 48.63% under conditions of varying permeability levels. A significant improvement in the water absorption profile was achieved. The plugging was carried out through a sand-filling pipe under varying permeability conditions and the pressure measuring points in the sand-filling pipe were sucessfully pressurized. The migration ability of the weak gel was good and the blocking rate was >85%.Keywords:temperature and salt tolerance;weak gel preparation;profile control;fluid flow direction;plugging performance
研究领域:
石油工程
·
材料科学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
COMPOSITES COMMUNICATIONS
·
2025
·
IF 7.7
Ran He,Zhenguo Wang,Yalin Ni,Chang Cui,Zhao-Xia Guo,Baohua Guo,Xinlin Tuo
Developing carbon fiber (CF) composites that integrate flexibility, strength and extreme environmental adaptability has emerged as a new challenge, holding strategic significance for advanced high-tech fields. However, conventional polymer resins (e.g. polyurethane) employed in flexible CF composites exhibit inherent performance limitations in meeting the above requirements. Herein, heterocyclic aramid (HA), which has good flexibility and strength, inherent temperature resistance and good flame retardancy, is developed to prepare CF composites with carbon fabrics by solution impregnating and layer-by-layer stacking technique. The interfacial adhesion of the composites was evaluated at three different dimensions (fiber/HA, yarn/HA and fabric/HA) using microbond, yarn pull-out, and T-peeling tests. The flexural strength and modulus measured at three different temperatures (−55 °C, room temperature and 200 °C) show only a slight variation, revealing low and high temperature applicability. Dynamic impact testing showed that the composite with a high HA content has excellent impact toughness. The limiting oxygen index (LOI) is greater than 80 %, showing excellent flame retardancy. The composites are thermally stable up to 450 °C. This work demonstrates that HA as an efficient polymer resin can be successfully combined with CF fabric to prepare CF composites with integrated performance of flexibility, strength, temperature resistance and flame retardancy, showing the potential for applications in extreme environments.
研究领域:
材料科学
·
航空航天工程
✓ 已验证
产品关联
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
JOURNAL OF MATERIALS SCIENCE
·
2019
·Vol. 54
·期 24
·14752-14762
·
IF 3.442
Lyu Yahui,Gu Chenglin,Tao Jiaping,Yao Xue,Zhao Guang,Dai Caili
The temperature resistance, shear stability and salinity tolerance of the polymer are crucial as a chemical agent for enhanced oil recovery (EOR) involving high-temperature and high-salinity reservoirs. In this work, triethoxyvinylsilane (VTEO) molecules were first covalently bound to the surface of the graphene oxide (GO) to synthesize the sGO, and then, the sGO was copolymerized with acrylamide (AM) to prepare the PAM/sGO composite. The composite was also characterized by Fourier transform infrared spectroscopy, X-ray diffraction analysis, X-ray photoelectron spectroscopy and thermogravimetric analysis. Additionally, temperature resistance, shear stability and salinity tolerance were evaluated to determine the performance of the composite. These results indicate that the synthesized composite exhibits novel thermal-resistant, shear-stable and salinity-tolerant performance as a new EOR agent in high-temperature and high-salinity reservoirs. Furthermore, the stability mechanisms of the composite were revealed through the analysis of the interactions between GO sheets and polymer matrix in the microstructure.
研究领域:
材料科学
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石油工程
✓ 已验证
产品关联
DOI
高影响因子
Applied Sciences-Basel
·
2023
·Vol. 13
·期 7
·4378
·
IF 2.7
Qi Zuo,Zhihui Wang,Peng Li,Luyuan Yang,Zhaozheng Song
Two novel betaine surfactants with distinct hydrophilic headgroups were synthesized, including carboxybetaine surfactant (DCB) and sulfobetaine surfactant (DSB). Their properties of reducing the interfacial tension (IFT) of Xinjiang crude oil/water were studied under alkaline-free conditions, as were their thermal stability, wettability, and emulsification properties. The chemical structures of the target products were characterized and analyzed by using1H-NMR and13C-NMR. The experimental results indicate that the introduction of a benzene ring to the hydrophobic group can improve the solubility and high-temperature resistance of the betaine surfactant. Thermogravimetric analysis showed that the degradation temperature of the synthesized betaine was above 190 °C. As the concentration of the betaine solution increased, DSB (0.0750 mmol/L) showed a lower critical micelle concentration (CMC) than DCB (0.1852 mmol/L). The wetting ability of DCB was significantly higher than that of DSB, and their contact angles on paraffin film decreased to 28.36° and 35.26°. In addition, both DCB and DSB can reduce the IFT of Xinjiang crude oil/water to ultra-low levels (10−3mN/m) in the absence of alkali. The appropriate ion concentration has a synergistic effect on the surfactant to reduce the interfacial tension of oil/water and the effect of the three ions on the interfacial tension was as follows: Na+< Ca2+< Mg2+.Keywords:betaine surfactant;temperature resistance;interfacial tension;critical micelle concentration
研究领域:
化学工程
·
石油工程
✓ 已验证
产品关联
DOI
高影响因子
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
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
·
2021
·
IF 4.539
Meng Cun,Jincheng Mao,HaiLin Sun,Guo Wei,Feng Tang,Wenlong Zhang,Jizhen Tian,Xiaojiang Yang,Chong Lin,ZiGao Huang
In recent years, cationic surfactants have received extensive attention in cleaning fracturing fluid thickeners due to various unique properties. At the same time, the development of temperature-resistant and salt-resistant clean fracturing fluid is the key to deep well oil and gas resource development. In this study, the rigid-soft combined strategy is adopted for molecular structure designs. N,N -dimethylcyclohexylamine and epichlorohydrin are used as the initial reactants; after the ring-opening reaction occurs, they are quaternized with erucamide propyl dimethyl ammonium to synthesize a novel double-cation viscoelastic surfactant , SY–JS. With double-cationic charges on the head group, water molecules are selectively adsorbed around the cation lattice to increase the hydration layer, and thus, salt tolerance is improved. Cyclohexane with a rigid structure improves temperature resistance. The ultra-long unsaturated hydrophobic tail imparts excellent heat tolerance and dissolubility to the designed viscoelastic surfactant. The clean fracturing fluid prepared by 3 wt% SY–JS with 130,000 ppm NaCl or KCl performs well under a shear rate of 170 s −1 at 140 °C, and the apparent viscosity remains above 30 mPa s −1 after 120 min.. Additionally, the results show that single-tail surfactants exhibit excellent performance at approximately 140 °C. Afterward, the brine produced from Rumaila and Jiyuan oil fields is used to prepare brine-based clean fracturing fluids, and evaluations, including proppant suspension, gel breaking, and permeability damage, were conducted. The results show that the brine-based clean fracturing fluid completely meets the requirements of hydraulic fracturing industrial application.
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
JOURNAL OF APPLIED POLYMER SCIENCE
·
2018
·Vol. 136
·期 10
·47161
·
IF 1.901
Baofeng Hou,Hong He,Ruixiu Jia,Meilong Fu,Yanbin Cao,Shaoqun He,Liwen Luo,Youqing Huang
The synthesis and performance of a novel temperature-tolerant foamed resin for enhanced oil recovery were investigated using various methods, including infrared, NMR, scanning electron microscopy (SEM), and displacement experiments. Polycondensation of furfuryl alcohol prepolymers was confirmed by the infrared and NMR results. The poor temperature tolerance of furfuryl alcohol prepolymers after gelation at high temperatures is mainly due to the fracture of furan rings. The addition of ester additives is an effective method of increasing the temperature tolerance of the prepared foamed resins and can effectively reduce the weight-loss rate of the polycondensation products. The SEM results show that the skeleton structure of the foamed resin remains intact after high-temperature treatment. Thus, the novel plugging agent system has excellent thermal stability and still has a high strength (>0.8 MPa) after high-temperature aging treatment for 40 days, giving the prepared foamed resin a good plugging performance (plugging rate > 91%) at 250 °C. © 2018 Wiley Periodicals, Inc. J. Appl. Polym. Sci. 2019 , 136 , 47161.
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
Gels
·
2022
·Vol. 8
·期 9
·547
·
IF 4.432
Jian Li,Jinsheng Sun,Kaihe Lv,Yuxi Ji,Jintao Ji,Jingping Liu
With the continuous exploration and development of oil and gas resources to deep formations, the key treatment agents of water-based drilling fluids face severe challenges from high temperatures and salinity, and the development of high temperature and salt resistance filtration reducers has always been the focus of research in the field of oilfield chemistry. In this study, a nano-silica-modified co-polymer (NS-ANAD) gel was synthesized by using acrylamide, isopropylacrylamide, 2-acrylamide-2-methyl propane sulfonic acid, diallyl dimethyl ammonium chloride, and double-bond-modified inorganic silica particles (KH570-SiO2) through free radical co-polymerization. The introduction of nanotechnology enhances the polymer’s resistance to high temperature degradation, making it useful as a high-temperature-resistant fluid loss reducer. Moreover, the anions (sulfonates) and cations (quaternary ammonium) enhance the extension of the polymer and the adsorption on the surface of bentonite particles in a saline environment, which in turn improves the salt resistance of the polymer. The drilling fluids containing 2.0 wt% NS-ANAD co-polymer gels still show excellent rheological and filtration performance, even after aging in high temperature (200 °C) and high salinity (saturated salt) environments, showing great potential for application in deep and ultra-deep drilling engineering.Keywords:nano-modified polymers gels;fluid-loss additive;temperature- and salt-resistant;water-based drilling fluids;ultra-deep wells
研究领域:
石油化学工程
·
材料科学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
危险品化学品经营许可证（带存储）