Geoenergy Science and Engineering
·
2024
·
IF 0
Jian Wang,Jinsheng Sun,Xianbin Huang,Kaihe Lv,Xiaodong Dong,Yuan Geng,Shuixiang Xie
There is a lack of viscosity enhancers for high-temperature and high-density solid-free completion solutions in high-temperature and high-pressure oil and gas reservoirs. To address the problem of insufficient temperature resistance of biopolymers and poor performance of conventional viscosifiers in high-temperature and high-density solid-free completion fluids, an anti-temperature viscosifiers for high-density solid free completion fluids was synthesized using N,N-dimethylacrylamide(DMAA), diallyldimethylammonium chloride(DMDAAC) and the amphoteric ion [2-(Methacryloyloxy)ethyl]dimethyl-(3-sulfopropyl)ammonium Hydroxide(SBMA) as the main monomers. FPOD has salt-responsive properties. With the increase of brine concentration, the degree of stretching of FPOD molecular chain increased and formed a network structure through intermolecular forces, which provided a viscosity increasing effect on the solution. FPOD has good temperature resistance. The apparent viscosity of 1 wt% FPOD in 1.75 g/cm 3 CaBr 2 brine was 37 mPa·s, and after aging at 150 °C, the viscosity was still 32.5 mPa·s. The performance of FPOD before and after aging is better than other viscosifiers. FPOD is simple to prepare and has good viscosity enhancement effect in high density solid-free brines. Moreover, FPOD is well-compatible with other treatment agents for completion fluids, and the HTHP filtration loss of the completion fluid system with 2 wt% FPOD added at 150 °C is only 5 mL. FPOD could solve the problem of insufficient high temperature resistance and viscosity increasing performance of viscosifiers in high density brine completion fluids, and provide a new technical approach to drilling high-temperature and high-pressure oil and gas reservoirs.
研究领域:
石油工程
·
高分子化学
✓ 已验证
产品关联
DOI
RSC Advances
·
2021
·Vol. 11
·期 28
·17197-17205
·
IF 3.361
Bin Liu,Yanling Wang,Lei Liang,Yijin Zeng
Supercritical carbon dioxide (SC-CO2) fracturing technology has the characteristics of a large amount of fixed CO2 and anhydrous fracturing. It has great application potential for developing unconventional oil and gas resources and mitigating the greenhouse effect. However, the low viscosity of SC-CO2 limits the development of this technology. In this work, HS series thickeners were prepared via a ring-opening polymerization and hydrosilylation reaction by a molecular simulation-aided design method. The simulation results of cohesive energy density, interaction energy, and radial distribution function are consistent with the visualization experimental results, which proves that HS (hyperbranched siloxane) series thickeners have excellent solubility in SC-CO2. HS-3 is the best thickener in the HS series. At 305.15 K and 10 MPa, 5 wt% HS-3 (60 s−1) increases the viscosity of SC-CO2 by 151 times, and the apparent viscosity is 3.024 mPa s. The apparent viscosity of SC-CO2 was positively correlated with the pressure and concentration but negatively correlated with the temperature and shear rate. The results indicate that it is feasible to introduce an aliphatic group and polysiloxane into a SC-CO2 thickener by hydrosilylation.
研究领域:
石油工程
·
材料科学
·
化学工程
✓ 已验证
产品关联
DOI
PubMed
高影响因子
ENVIRONMENTAL SCIENCE AND POLLUTION RESEARCH
·
2022
·Vol. 29
·期 25
·37815-37826
·
IF 5.19
Li Qiang,Wang Fuling,Forson Kobina,Zhang Jinyan,Zhang Chenglin,Chen Juan,Xu Ning,Wang Yanling
The fracturing property of liquid CO 2 fracturing fluid varies greatly due to the rheology of fracturing fluid during fracturing process. The main objective of this investigation is to study the rheology property of thickened liquid CO 2 by measuring the viscosity of thickened liquid CO 2 in different physical parameters of this prepared thickener and explain the causes of rheological changes. The results show that thickener content, branching content, and molecular weight of a thickener for all could significantly improve the rheology of liquid CO 2 ; the consistency coefficient K increased as they rose, but the rheological index n presented a decreased trend. Meanwhile, the mesh structure is proposed as a model to explain the rheological changes, and the large wetting angle means an excellent backflow, low reservoir damage, and low adsorption property. These results herein provide a basic reference to improve the CO 2 fracturing technology and molecular design of CO 2 thickener.
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
Materials
·
2024
·Vol. 17
·期 11
·2559
·
IF 3.1
Chengyu Huang,Peng Zhang,Bo Li,Mingchen Sun,Hansong Liu,Jinsong Sun,Yan Zhao,Jianwen Bao
Carbon-fiber-reinforced polyimide (PI) resin composites have gained significant attention in the field of continuous-fiber-reinforced polymers, in which the interfacial bonding between carbon fiber and matrix resin has been an important research direction. This study designed and prepared a water-soluble thermoplastic polyamide acid sizing agent to improve the wettability of carbon fiber, enhance the van der Waals forces between carbon fiber and resin and strengthen the chemical bonding between the sizing agent and the alkyne-capped polyimide resin by introducing alkyne-containing functional groups into the sizing agent. This study found that the addition of a sizing layer effectively bridged the large modulus difference between the fiber and resin regions, resulting in the formation of an interfacial layer approximately 85 nm thick. This layer facilitated the transfer of stress from the matrix to the reinforced carbon fiber, leading to a significant improvement in the interfacial properties of the composites. Adjusting the concentration of the sizing agent showed that composites treated with 3% had the best interfacial properties. The interfacial shear strength increased from 82.08 MPa to 108.62 MPa (32.33%) compared to unsized carbon fiber. This research is significant for developing sizing agents suitable for carbon-fiber-reinforced polyimide composites.
研究领域:
材料科学
·
复合材料工程
✓ 已验证
产品关联
DOI
PubMed
高影响因子
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
·
2023
·
IF 5.2
Xiaodong Dong,Jinsheng Sun,Xianbin Huang,Kaihe Lv,Yuan Geng,Fengbao Liu,Zonglun Wang,Xianfa Zhang
ABSTRACT In the process of developing deep oil and gas resources, the problem of high temperature and high salinity in deep strata has become a serious challenge faced by water-based drilling fluids. Under high temperature and high salinity conditions, drilling fluids must maintain good rheological properties to ensure safe and efficient drilling work. In this study, a temperature- and salt-resistant viscosifier (DASL) was synthesized using N, N-dimethylacrylamide, 2-Acrylamido-2-methylpropane sulfonic acid, sodium p-styrene sulfonate, and lauryl methacrylate as monomers with a double backbone structure of micro crosslinking and hydrophobic association structures. The results of pyrene fluorescence probe test and transmission electron microscopy observation showed that DASL has an obvious hydrophobic associative structure. Moreover, due to the presence of microcrosslinked structure, DASL exhibits good shear thinning property and thixotropy in aqueous solution. Under the conditions of 200℃ and 35 wt% NaCl, the apparent viscosity of the drilling fluid with 2 wt% DASL added was 24.5 mPa⸱s, and the filtration was only 9.2 mL. In addition, mechanism studies have shown that the dual skeleton structure of DASL improves its temperature and salt resistance. DASL can adsorb and bridge with bentonite particles, increase the internal friction and structural viscosity of the drilling fluid, enhance the internal mesh structure of the drilling fluid, improve the colloidal stability of the drilling fluid, and maintain a reasonable particle size distribution of the bentonite particles, which enable DASL to significantly increase the viscosity of the drilling fluid while reducing the filtration loss of the drilling fluid. This work demonstrates that polymers with dual skeleton structures of micro crosslinking and hydrophobic association have good application effects as temperature- and salt-resistant viscosifier for water-based drilling fluids.
研究领域:
石油工程
·
高分子化学
·
材料科学
✓ 已验证
产品关联
DOI
高影响因子
Crystals
·
2025
·Vol. 15
·期 1
·82
·
IF 2.4
Yue Gao,Xiaobo Wang,Yun Cheng,Xuan Qi,Hao Yan
A high-temperature-resistant copolymer thickener (DT) was synthesized through free radical polymerization, utilizing monomers such as N-vinylformamide (NVF), divinylbenzene (DVB), and acrylamide (AM) as the primary raw materials. The polymer system’s structure was characterized using FTIR and 1H NMR, while its thermal properties were analyzed through thermogravimetric analysis. The viscosity changes of the polymers were evaluated before and after high-temperature aging at various temperatures. The results indicated that the viscosity retention rate of the thickener DT in the base slurry at 240 °C and 15% NaCl was 87.1%. Additionally, it exhibited varying anti-aging cycles between 200 °C and 240 °C. In a slurry with 25% NaCl, the viscosity retention rate reached 130% at 200 °C. High-temperature and high-pressure rheological tests demonstrated that drilling fluids containing DT exhibit consistent rheological behavior within the temperature range of 150 °C to 180 °C, which aids in stabilizing the viscosity and strength of drilling fluids at elevated temperatures.
研究领域:
化学工程
·
材料科学
✓ 已验证
产品关联
DOI
高影响因子
ACS Omega
·
2023
·
IF 4.1
Yunfeng Liu,Lang Zhou,Yongfan Tang,Qiang Liu,Wei Li,Yan Zhang
Deep carbonate rock oil and gas reservoir is an important support for increasing oil and gas storage and production at present. The environment of ultradeep and ultrahigh-temperature reservoirs has put forward higher technical requirements for reservoir modification acid technology. Moreover, gelling acid is the main acid solution for high-temperature reservoir acidizing transformation, with a temperature resistance of no more than 180 °C, and the gelling agent is one of the key factors restricting its high-temperature resistance performance. In this paper, AM, AMPS, DMDAAC, and NVP were used as monomers, oxidants, and reducing agents to prepare a high-temperature-resistant polymer gel through polymerization. At the same time, microcapsules were prepared by in situ polymerization using epoxy resin as the wall material. The indoor performance evaluation results indicate that the gelling agent is easily soluble in high-concentration acid solution and has good viscosity increasing effect. At 180 °C and 170 s–1 shear rate, 0.8% mass fraction of the gelling agent was dissolved in 20% mass fraction of hydrochloric acid. After shearing for 60 min, the viscosity remained at about 22.45 mPa·s, demonstrating good temperature resistance and shear resistance, and its performance was superior to existing commonly used gelling agent products.
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
危险品化学品经营许可证（带存储）