Energies
·
2022
·Vol. 15
·期 22
·8737
·
IF 3.252
Yixin Chen,Yu Sang,Jianchun Guo,Jian Yang,Weihua Chen,Fei Liu,Ji Zeng,Botao Tang
Hydraulic fracturing is an important technology for the stimulation of oil and gas reservoirs. Conventional fracturing technology based on “sand-carrying” faces some challenges such as sand plugs; incompatibility with the well completion method; damage to the reservoir caused by the incomplete gel-breaking of the fracturing fluid; solid proppants inefficiently turning the corner in complex fracture networks, and so on. In this paper, a novel self-generated proppant fracturing fluid system is proposed to solve the above problems caused by “sand-carrying”. The advantage of the fracturing fluid system is that in the whole process of fracturing, no solid proppants will be injected. The fracturing fluid itself will transform into solid proppants in the induced fractures under high temperatures to resist fracture closure stress. The fluid system consists of two kinds of liquids. One is the phase change liquid (PCL), which occurs as a liquid–solid phase change at high-formation temperatures to form a solid proppant. The other is the non-phase change liquid (NPCL), which controls the dispersity of the PCL in the two-phase fluid system. The main building block of the PCL is confirmed to be the bisphenol-A diglycidyl ether-type epoxy resin, whereas the NPCL is mainly composed of surfactants. The viscosity, phase-change temperature, and time of the fracturing fluid system are, respectively, about 30 mPa·s, 80 °C, and 20 min.Keywords:hydraulic fracturing;fracturing fluid;proppants;self-propping;conductivity
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
Juan Zhang,Qiqi Niu,Yuan Gao,Qichao Lv,Zhaoxia Dong,Zihao Yang
Clean fracturing fluids are widely used in reservoir stimulation and increasing production due to their characteristics of simple preparation, no residue, easy flowback, and low damage. At present, clean fracturing fluids are mainly prepared by cationic surfactants as main agent and inorganic or organic salts as additives, which can lead to unavoidable losses of cationic surfactants due to their adsorption in the formation. Anionic-cationic surfactants composite system can not only compensate for the shortcomings of a single surfactant system, but also improve the reservoir adaptability of the surfactant system. In this paper, a clean fracturing fluid was prepared with long-chain anionic surfactant, Sodium erucate (NaOEr), as main agent and a series of cationic surfactants with different as additive. Then, the aggregation behavior of mixed system was determined by visual appearance, rheology experiments, differential scanning calorimetry and cryogenic transmission electron microscopy. The phase transition mechanism induced by temperature was proposed, and the performance of the mixed system as a fracturing fluid was evaluated. The results showed the mixed systems could self-assemble into wormlike micelles when the length of hydrophobic carbon chains of cationic surfactant was 6 and 8. Increasing the length of the hydrophobic carbon chain could enhance the electrostatic effect, leading to precipitation in the mixed system. When the ratio of cationic surfactant was between 0.5 and 0.6 and the concentration was between 68 and 175 mmol∙L -1 , the mixed systems tended to form three-dimensional structures by entangling and stacking wormlike micelles, showing high viscoelasticity and viscosity. The aggregation structure of the mixed system transformed from vesicles to wormlike micelles at 46.8 °C, which is attributed to the transition of carbon chains of NaOEr from non-flexible to flexible. Finally, the mixed system as a fracturing fluid has good shear resistance and temperature resistance. The viscosity of NaOEr/HTAB can reach above 50 mPa⋅s after sheared for 60 min at the conditions of 170 s −1 and 80 °C. This study provides an anionic clean fracturing fluid and broaden the application of viscoelastic surfactants in oilfield development.
研究领域:
石油工程
·
材料科学
·
化学工程
·
胶体与表面化学
✓ 已验证
产品关联
DOI
高影响因子
MOLECULES
·
2024
·Vol. 29
·期 12
·2798
·
IF 4.2
Shenglong Shi,Jinsheng Sun,Shanbo Mu,Kaihe Lv,Jingping Liu,Yingrui Bai,Jintang Wang,Xianbin Huang,Jiafeng Jin,Jian Li
To investigate the effect of the chemical composition of a metal–organic crosslinker on the performances of fracturing fluid in high-temperature conditions, four zirconium (Zr) crosslinkers and one aluminum–zirconium (Al-Zr) crosslinker with a polyacrylamide were used. The crosslinkers possessed the same Zr concentration, but they differed in component amounts and the order of the addition of the crosslinker components, leading to different chemical compositions in the crosslinkers. The fracturing fluids prepared by different tested crosslinkers were compared in terms of properties of rheological behavior, sand-carrying ability, microstructure, and gel breaking characteristics. The results showed that the fracturing fluids prepared by zirconium lactic acid, ethanediamine, and sorbitol crosslinkers offered the slowest viscosity development and highest final viscosity compared to the zirconium lactic acid crosslinker and the zirconium lactic acid and ethanediamine crosslinker. The zirconium sorbitol, lactic acid, and ethanediamine crosslinker exhibited a faster crosslinking rate and a higher final viscosity than the zirconium lactic acid, ethanediamine, and sorbitol crosslinker; the crosslinker showed crosslinking density and crosslinking reactivity, resulting in more crosslinking sites and a higher strength in the fracturing fluid. The Al-Zr-based crosslinker possessed better properties in temperature and shear resistance, viscoelasticity, shear recovery, and sand-carrying ability than the Zr-based crosslinker due to the synergistic crosslinking effect of aluminum and zirconium ions. The tertiary release gelation mechanism of the Al-Zr-based fracturing fluid achieved a temperature resistance performance in the form of continuous crosslinking, avoiding the excessive crosslinking dehydration and reducing viscosity loss caused by early shear damage. These results indicated that the chemical compositions of metal–organic crosslinkers were important factors in determining the properties of fracturing fluids. Therefore, the appropriate type of crosslinker could save costs without adding the additional components required for high-temperature reservoirs.
研究领域:
石油工程
·
材料化学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
Desalination and Water Treatment
·
2024
·
IF 1
Ying Zhang,Xule Chen,Miao Dong,Meiyan Li,Chengwen Wang,Yanzong Zhang
During the process of oilfield wastewater reuse, residual Boron in fracturing flowback fluid will lead to premature crosslinking with gelling agents, resulting in excessive viscosity at the front end of the fracturing fluid configuration. This phenomenon has heavily influenced the reuse of wastewater. Electrocoagulation (EC), as an effective approach to decreasing Boron concentration, has been widely studied, while further research of Boron removal from complicated wastewater is required to optimize. EC parameters were investigated to explore the optimal Boron removal effect of Fe, Al and Fe-Al three combined anodes. Under 46.3–57.2 mA/cm 2 , 90 min and pH of 9, Fe-Al anodes exhibit the best effect of Boron removal (84% ± 1.5%). Furthermore, high adaptive capacity of low current density and suitable pH confirm the best choice of Fe-Al combined anodes. Scanning electron microscopy (SEM), Fourier transform infrared spectroscopy (FTIR) and X-ray photoelectron spectroscopy (XPS) demonstrate the complexation between Boron and metallic oxide. Finally, the common removal of various pollutants including Ca, Cl, K and Na further conduces to the reuse of oil wastewater.
研究领域:
环境科学
·
废水处理
✓ 已验证
产品关联
DOI
高影响因子
JOURNAL OF DISPERSION SCIENCE AND TECHNOLOGY
·
2020
·
IF 1.701
Kai Zheng,Yilin Deng,Hui Cao
To improve the properties of xanthan gum (XG), 3-chloro-2-hydroxypropyltrimethylammonium chloride and propylene oxide were used as modifiers to etherify XG and to obtain cationic hydroxypropyl xanthan gum (HCXG), and cationic hydroxypropyl xanthan gum (CHCXG), further optimized by super-gravity reaction. The structure of the product was characterized by infrared spectroscopy and nuclear magnetic resonance. The rheological properties of XG, HCXG, and CHCXG solutions and their performance as fracturing fluids were studied. Infrared and nuclear magnetic test results showed that the cationic etherification agent and hydroxypropyl group were successfully connected to XG, and the degree of substitution of CHCXG was higher. The rheological properties of the CHCXG solution and the performance of the fracturing fluid base fluid were superior to those of the XG and HCXG solutions. The viscosity of the solution after the super-gravity modification was further increased, and the apparent viscosity of the 0.4% CHCXG solution was 28.96% higher than that of the HCXG solution. After XG modification, the solution strength, yield stress, viscoelasticity, temperature resistance, and shear resistance were all significantly improved. The rheological properties of the HCXG solution and the performance of the fracturing fluid base fluid are good and can be used for fracturing fluid thickener.
研究领域:
生物化学
·
材料科学
·
石油工程
✓ 已验证
DOI
高影响因子
ACS Omega
·
2024
·
IF 3.7
Qing Guo,Ze Li,Xuanxiang Zeng,Dan Li,Huiming An,Li Zhao,Liang Tao,Qiang Li
Reduction of the reservoir permeability during supercritical CO2 fracturing caused significant reservoir damage, which directly affects the crude oil recovery rate. This investigation explored a novel thickener for supercritical CO2 fracturing fluid, this CO2 thickener not only effectively improves the viscosity and rheological properties of CO2 fracturing fluid but also contributes to reduce reservoir damage and improve permeability. The research results indicated that the synthesized CO2 thickener (3 wt %) can increase the apparent viscosity of supercritical CO2 fracturing fluid to 7 mPa·s, and a 9% matrix permeability damage rate and a 0.5 mD permeability decrease value are shown in a 3% CO2 fracturing fluid. However, 3 wt % of commercial CO2 thickener only increases the apparent viscosity of supercritical CO2 fracturing fluid to 3 mPa·s, while the reservoir damage rate increases to 13%. Two thickeners exhibit completely different damage capabilities to the reservoir, and the synthesized CO2 thickener shows excellent characteristics of reducing reservoir permeability and is also conducive to protecting shale reservoirs. Furthermore, supercritical CO2 fracturing fluid containing synthetic thickeners has better temperature and shear resistance compared with commercial thickeners. This may be because the synthesized thickener and the micro grid formed by supercritical CO2 reduce the adsorption in shale crevices, but a large amount of commercial thickeners can adsorb on the surface of shale.
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
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
POLYMER
·
2025
·
IF 4.5
Xiaoqin Cao,Shiyuan Wang,Runxi Wang,Zhenghua Sun,Yujun Feng,Hongyao Yin
Partially hydrolyzed polyacrylamide (HPAM) hydrogels are widely used as fracturing fluids for extracting underground hydrocarbon resources. Weighting salts are incorporated to enhance hydrogel density to address the extreme pressure encountered in ultra-deep reservoirs. These salts exert significant effects on performance; however, the underlying mechanisms remain poorly understood, and the development of high-performance fracturing fluids remains a significant challenge. This study systematically examines the influence of potassium formate (HCOOK) and sodium bromide (NaBr) as weighting agents on the viscoelasticity of high-density HPAM hydrogels. The findings indicate that HCOOK exerts a more pronounced adverse impact on the viscoelasticity of HPAM hydrogels compared to NaBr. Molecular dynamics simulations reveal that the inferior viscoelasticity of the HCOOK-based polymer hydrogels is attributed to stronger supramolecular interactions between the crosslinker and HCOOK. This study develops an enhanced-performance high-density fracturing fluid with a density of up to 1.40 g/cm 3 , a maximum drag reduction rate of 75.1 %, and temperature tolerance up to 160 °C by integrating ultra-high molecular weight HPAM, a dual crosslinking strategy, and NaBr as weighting salt. This research not only provides fundamental insights into the complex interactions among weighting agents, crosslinkers, and polymers but also presents an enhanced-performance high-density fracturing fluid for ultra-deep hydrocarbon reservoirs.
研究领域:
高分子科学
·
石油工程
·
材料科学
·
化学工程
·
地质学
✓ 已验证
产品关联
DOI
高影响因子
ENVIRONMENTAL RESEARCH
·
2024
·
IF 7.7
Haiqing Chang,Yingyuan Zhu,Naiming Liu,Pengwei Ji,Zhongsen Yan,Xiaoxiang Cheng,Dan Qu,Heng Liang,Fangshu Qu
Low pressure membrane takes a great role in hydraulic fracturing wastewater (HFW), while membrane fouling is a critical issue for the stable operation of microfiltration (MF). This study focused on fouling mitigation by sodium percarbonate (SPC) oxidation, activated by ultraviolet (UV) and ferrous ion (Fe(II)). The higher the concentration of oxidizer, the better the anti-fouling performance of MF membrane. Unlike severe MF fouling without oxidation (17.26 L/(m 2 ·h)), UV/SPC and Fe(II)/SPC under optimized dosage improved the final flux to 740 and 1553 L/(m 2 ·h), respectively, and the latter generated Fe(III) which acted as a coagulant. Fe(II)/SPC oxidation enabled a shift in fouling mechanism from complete blocking to cake filtration, while UV/SPC oxidation changed it to standard blockage. UV/SPC oxidation was stronger than Fe(II)/SPC oxidation in removing UV 254 and fluorescent organics for higher oxidizing capacity, but the opposite was noted for DOC removal. The deposited foulants on membrane surface after oxidation decreased by at least 88% compared to untreated HFW. Correlation analysis showed that UV 254, DOC and organic fraction were key parameters responsible for membrane fouling (correlation coefficient＞0.80), oxidizing capacity and turbidity after oxidation were also important parameters. These results provide new insights for fouling control during the HFW treatment.
研究领域:
环境科学
·
化学工程
✓ 已验证
产品关联
DOI
PubMed
高影响因子
Gels
·
2022
·Vol. 8
·期 11
·722
·
IF 4.432
Shenglong Shi,Jinsheng Sun,Kaihe Lv,Jingping Liu,Yingrui Bai,Jintang Wang,Xianbin Huang,Jiafeng Jin,Jian Li
To overcome the problems of long dissolution time and high investment in surface facilities of powder thickeners in hydraulic fracturing, a novel suspension of a thickener as a fracturing fluid was prepared using powder polyacrylamide, nano-silica, and polyethylene glycol by high-speed mixing. The suspension and powder were compared in terms of properties of solubility, rheological behavior, sand carrying, drag reduction, and gel breaking. The results showed that the suspension could be quickly diluted in brine within 5 min, whereas the dissolution time of powder was 120 min. The suspension exhibited better performance in salt resistance, temperature resistance, shear resistance, viscoelasticity, sand carrying, and drag reduction than powder. The powder solution was broken more easily and had a lower viscosity than suspension diluent. These improvements in properties of the suspension were due to the dispersion of nano-silica in the polymer matrix; the mobility of thickener chains was inhibited by the steric hindrance of the nano-silica. Nano-silica particles acted as crosslinkers by attaching thickener chains, which strengthened the network structure of the thickener solution. The presence of hydrogen bonds between the thickener matrix and the nano-silica restricted the local movement of thickener chains, leading to a stronger spatial network. Therefore, this novel suspension showed good potential for fracturing applications.Keywords:hydraulic fracturing;suspension;nano-silica;powder thickener;network structure
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
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
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
危险品化学品经营许可证（带存储）