JOURNAL OF APPLIED POLYMER SCIENCE
·
2024
·
IF 2.7
YuMei Luo,QingGuo Shang,Hua Hu,Xiaodong Bai
In order to reduce the economic loss caused by well leakage and the lag of drilling progress, it is very important to use plugging materials reasonably and effectively. Expandable polymer materials can better fill cracks and holes of different sizes by absorbing water expansion and deforming. In this article, an expandable polymer plugging agent (PSMAN) was prepared by soap-free emulsion polymerization using methyl methacrylate (MMA), styrene (St), 2-acrylamide-2-methylpropanesulfonic acid (AMPS) as reaction monomers, N -hydroxymethyl acrylamide (NMA) as a cross-linking agent, and ammonium persulfate (APS) as initiator. The optimal synthesis conditions were determined by designing the orthogonal experiments, and the various properties of the materials were tested and evaluated. The experimental results show that PSMAN has good high temperature resistance, spherical structure, and median particle size of 15.099 μm, and the water absorption rate of room temperature at 24 h reaches 37.8 g/g, and pressure bearing capacity can reach 5 MPa. The addition of polymer to water-based drilling fluid can increase the viscosity of drilling fluid and improve the rheological properties of drilling fluid by a small amount. Under normal temperature and medium pressure, the polymer can form a dense film on the surface of the mud cake, thereby reducing the filtration of drilling fluid and effectively improving the stability of the wellbore.
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
JOURNAL OF APPLIED POLYMER SCIENCE
·
2024
·Vol. 141
·期 31
·e55732
·
IF 2.7
Yumei Luo,Lianci Wu,Yancheng Yan,Qingguo Shang,Min Huang,Kefu Pu,Xiaodong Bai
In the process of unconventional oil and gas exploitation, the invasion of a large amount of drilling fluid into the formation is one of the most critical reasons leading to wellbore instability. A temperature-sensitive polymer (AOS) was synthesized from acrylamide, oligo (ethylene glycol) methyl ether methacrylate (OEGMA), and sodium p-styrene sulfonate by emulsion polymerization. The material is a solid-free fluid with good fluidity at room temperature, after injection into the formation, the fluid is gradually transformed into hard gel above the lower critical solution temperature (LCST) (90°C), thus blocking micro-fractures and improving wellbore stability. Infrared and NMR characterization confirmed the successful preparation of the target product. The transmittance of AOS with ambient temperature was measured by UV–vis spectrophotometer, and the LCST behavior of AOS was verified by rheological and viscoelastic measurements. The interaction mechanism between AOS and sodium bentonite was evaluated according to the American Petroleum Institute standard. The results show that after aging at 180°C, the filtration loss is reduced by 93%, and the medium permeability (100, 200 mD) formation is effectively plugged, with a plugging efficiency is as high as 74.7%.
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
·
2024
·Vol. 10
·期 1
·73
·
IF 5
Quanyang Wang,Jing Cai,Jiannan Wang,Chenghua Zhou,Xinxin Wen,Jiang Zhang,Hui Mao
With the gradual deepening of the exploration and development of deep and ultra-deep oil and gas resources, the problem of lost circulation in drilling operations is becoming more and more complex. From field experience, conventional plugging materials cannot fully meet the technical requirements of plugging operations in drilling engineering. In this study, a high-temperature- and salt-resistant polymer HDZ−A was synthesized. A high-temperature and delayed crosslinking polymer gel plugging agent can be prepared by adding a certain concentration of a crosslinking agent and a retarder. In this paper, the optimum synthesis conditions of the HDZ−A were determined with orthogonal experiments using viscoelasticity and viscosity as evaluation criteria for newly developed polymers. The molecular structure, temperature resistance, and relative molecular mass of HDZ−A were determined using infrared spectroscopy, nuclear magnetic resonance spectroscopy, and gel permeation chromatography. In addition, the optimal formula of the gel plugging agent was determined using gel strength as the evaluation standard. The results show that the newly developed gel plugging agent has stable performance after high-temperature crosslinking, and can resist high temperatures of 160 °C during formation. Under conditions of 160 °C, the gelation time can reach 4.5 h, and the plugging efficiency can reach more than 97%. Finally, the field test of the newly developed high-temperature-resistant delayed crosslinking polymer gel plugging agent was carried out in the direct exploration well KT-14X in the Ordos Basin. The field test showed that the plugging effect of the HDZ−A gel plugging agent was remarkable.
研究领域:
石油工程
·
高分子化学
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材料科学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
Gels
·
2024
·Vol. 10
·期 8
·511
·
IF 5
Xiongwei Liu,Biao Qi,Xiuping Chen,Ziyao Shen,Jingbin Yang
Lost circulation is a common and complicated situation in drilling engineering. Serious lost circulation may lead to pressure drop in the well, affect normal drilling operations, and even cause wellbore instability, formation fluid flooding into the wellbore, and blowout. Therefore, appropriate preventive and treatment measures need to be taken to ensure the safe and smooth operation of drilling operations. So, it is necessary to conduct in-depth research on the development and performance of the plugging materials. In this study, urea formaldehyde resin with high temperature resistance and strength was used as the main raw material, and the curing conditions were optimized and adjusted by adding a variety of additives. The curing time, compressive strength, temperature resistance, and other key performance indexes of the resin plugging agent were studied, and a resin plugging agent system with excellent plugging performance was prepared. The formula is as follows: 25% urea formaldehyde resin +1% betaine +1% silane coupling agent KH-570 + 3% ammonium chloride +1% hexamethylenetetramine +1% sodium carboxymethyl cellulose. The optimal curing temperature is between 60 and 80 °C, with a controllable curing time of 1–3 h. Experimental studies examined the rheological and curing properties of the resin plugging agent system. The results showed that the viscosity of the high-strength curable resin system before curing remained stable with increasing shear rates. Additionally, the storage modulus and loss modulus of the resin solutions increased with shear stress, with the loss modulus being greater than the storage modulus, indicating a viscous fluid. The study also investigated the effect of different salt ion concentrations on the curing effect of the resin plugging system. The results showed that formation water containing Na+at concentrations between 500 mg/L and 10,000 mg/L increased the resin’s curing strength and reduced curing time. However, excessively high concentrations at lower temperatures reduced the curing strength. Formation water containing Ca2+increased the curing time of the resin plugging system and significantly impacted the curing strength, reducing it to some extent. Moreover, the high-strength curable resin plugging agent system can effectively stay in various fracture types (parallel, wedge-shaped) and different fracture sizes, forming a high-strength consolidation under certain temperature conditions for effective plugging. In wedge-shaped fractures with a width of 10 mm, the breakthrough pressure of the high-strength curable resin plugging agent system reached 8.1 MPa. As the fracture width decreases, the breakthrough pressure increases, reaching 9.98 MPa in wedge-shaped fractures with an outlet fracture width of 3 mm, forming a high-strength plugging layer. This research provides new ideas and methods for solving drilling fluid loss in fractured loss zones and has certain application and promotion value.
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
Polymers
·
2023
·Vol. 15
·期 13
·2815
·
IF 5
Zhiquan Zhang,Baimei Dai,Peng Xu
Due to the increasing difficulty of drilling in the later stages of oil and gas field development, the development of micro-pores and micro-fractures is becoming common. Conventional plugging agents have relatively large particle sizes. So, choosing the appropriate plugging agent can prevent leakages. Using the inverse emulsion polymerization method, acrylamide, 2-acrylamide-2-methylpropane sulfonic acid and acrylic acid were selected to be the main reaction monomers, N,N′-methylenebisacrylamide was used as a crosslinking agent, sorbitan monostearate and polyoxyethylene sorbitan anhydride monostearate were used as emulsifiers, and 2,2′-azobis(2-methylpropionamidine) dihydrochloride was used as the initiator to synthesize a nano-scale plugging agent for oil-based drilling fluid. The plugging agent was characterized using infrared spectroscopy, scanning electron microscopy, and thermogravimetry analysis. The results showed that the plugging agent is spherical and uniform in size, with particles being in the submicron range. Additionally, it exhibited strong temperature resistance. Finally, the performance of the plugging agent was evaluated via experiments conducted under normal temperature and pressure, high-temperature and high-pressure, and core-plugging conditions. After adding the plugging agent to the oil-based drilling fluid, the basic rheological properties of the oil-based drilling fluid were not significantly affected. Furthermore, the filtration loss was significantly reduced under normal temperature and pressure, as well as under high-temperature and high-pressure conditions, after aging. When the plugging agent with 3% concentration was added, the reduction rate of pore core permeability reached 96.04%. Therefore, the plugging agent for the oil-based drilling fluid can effectively improve the wellbore stability and has a promising potential for field applications.Keywords:polymer microspheres;nano-scale;oil-based drilling fluid;plugging agent;inverse emulsion polymerization
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
·
2023
·Vol. 141
·期 9
·e55005
·
IF 3
Xiaodong Bai,Moubo Wang,Yu Chen,Lianci Wu,Jingya Yu,Yumei Luo
The P(AM- co -AMPS)/SA DN hydrogel was synthesized through aqueous polymerization in this study. It formed a crosslinking network with hydrophobic associations between acrylamide (AM) and lauryl methacrylate (LMA), as well as an ionic bond network involving sodium alginate and Ca 2+ . To enhance its high-temperature resistance, 2-acrylamide-2-methylpropane sulfonic acid (AMPS) was incorporated into the hydrogel formulation. The structure of the hydrogel was characterized using Fourier transform infrared spectrometer (FTIR), thermogravimetric analyzer (TGA), and scanning electron microscopy (SEM) techniques. Results demonstrated that the hydrogel exhibited excellent temperature resistance and possessed a porous structure. Mechanical testing revealed a high tensile strength of 110 kPa, elongation at break of 995.31%, along with good fatigue resistance and self-recovery performance during multiple cyclic stretching. Healing experiments indicated that the healing strength of the hydrogel was influenced by temperature variations. Furthermore, pressure plugging tests were conducted on steel models with crack widths of 0.5 and 1 mm, respectively; it was found that the 0.8%P(AM- co -AMPS)/SA DN hydrogel could withstand pressures up to 4.5 MPa at a temperature of 70°C. This novel hydrogel material exhibits remarkable mechanical properties along with certain self-healing capabilities, making it suitable for leak control applications.
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
JOURNAL OF APPLIED POLYMER SCIENCE
·
2023
·Vol. 140
·期 21
·e53874
·
IF 3
Yuanzhi Qu,Xinyu Zhou,Han Ren,YueHui Yuan,Wenchao Zhang,Gang Yang,Xianfa Zhang
During drilling in deep formations, it is challenging to form an effective plug to avoid borehole collapse under high temperatures and pressures. In order to simultaneously improve the high-temperature resistance and interparticle interaction capability of traditional plugging agents, a new gel plugging agent (PCAA) with self-healing capability was developed using chitosan, acrylamide, and acrylic acid. The rheological properties of the PCAA indicate that all monomers of PCAA are essential components to improve the performance of the plugging agent. Each monomer has a unique capability, such as acrylamide playing a dominant role in the construction of the gel network, acrylic acid enhancing the gel structure, and chitosan improving the gel adhesion. PCAA can be stretched to 8.8 times prolonged, and its tensile stresses and self-healing rate in 16 h are 17.2 kPa and 78.5%, respectively. Under the extreme conditions of 180°C and 8% NaCl, PCAA still performs well in preventing drilling fluid from invading the sand layer due to its self-healing and plugging effects. In addition, the interaction of PCAA and clay improves the stability, rheological properties, and filtration reduction of drilling fluids at high temperatures. The developed PCAA has been successfully applied to the field with extreme conditions, providing insights into plugging agent design.
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
·
2022
·
IF 5.518
Xianbin Huang,Xu Meng,Kaihe Lv,Zhen Zhang,Lihu Cao,Ren Wang,Jie Feng,Yicheng Wu,Wenbo Sheng
Nano-plugging agents (NPAs) are very important to stabilize the wellbore by reducing pressure transmission and drilling fluid invasion during drilling engineering. A functionalized polystyrene latex (FPL) was synthesized by micellar polymerization as a NPA for drilling fluids. The particle size and thermal stability of FPL were characterized by particle size analysis and thermogravimetric analysis (TGA). The experimental results showed that the initial thermal decomposition temperature of FPL was 310.6 ℃. The medium value of particle size distribution (D50) of FPL decreased from to 371–235 nm after aging at 220 ℃, indicating that FPL had good temperature resistance property. The plugging method and plugging performance of FPL for four filter media with pore sizes from 0.01 µm to 10 µm were introduced. FPL itself was difficult to plug the filter papers and ceramic filter disks, but FPL could reduce fluid loss of bentonite suspensions. SEM observation indicates that FPL could improve the quality of mud cakes and plug the small pores of ceramic filter disks. For microporous membranes and artificial mud cakes with low permeability, FPL aqueous suspensions had a good plugging performance. The plugging experimental results conformed well to the 2/3 bridging rule. This paper provides a good reference for the development of high temperature NPAs and the establishment of evaluation methods of NPAs.
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 APPLIED POLYMER SCIENCE
·
2022
·Vol. 139
·期 28
·e52524
·
IF 3.057
Xiaodong Bai,Xuemei Yong,Yumei Luo,Licheng Deng,Ke Li,Yi Zhou
In the process of drilling with water-based drilling fluid, polymer plugging agent is very important to solve the problem of wellbore instability in the formation with micropores and microfractures. In this study, N -isopropyl acrylamide and 2-acrylamide-2-methylpropanesulfonic acid were grafted onto the surface of SiO 2 modified by vinyl trimethoxysilane by reverse suspension polymerization reaction, and a heat-sensitive polymer plugging agent was synthesized. The structure analysis showed that the synthetic material was the target product, with a particle size of 49.665 μm, high-temperature resistance and sensitive temperature response behavior. According to laboratory evaluation experiments, it can be seen that the addition of the polymer increased the electrostatic stability of bentonite particles and had a chemical inhibition effect. Under the action of temperature and pressure, the synthesized temperature sensitive plugging agent formed a dense hydrophobic membrane on the surface of mud cake, which physically sealed the microcracks and pores, and reduced the filtration loss, so as to greatly improve the stability of shale. The experimental results showed that the synthesized temperature sensitive plugging agent has excellent high-temperature resistance and plugging performance.
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
Geoenergy Science and Engineering
·
2024
·
IF 0
Zhe Li,Xianbin Huang,Haiying Lu,Kaihe Lv,Yuan Geng,Lingling Ren,Chao Zhang
Wellbore instability of deep and ultra-deep formations is critical in the drilling industry. To solve the problem of plugging material failure in high-temperature environments and plug micron-scale pores, it is crucial to develop a plugging agent that can maintain its effectiveness in high-temperature scenarios. In this study, a high-temperature-resistant plugging agent was synthesized by emulsion polymerization. The copolymer consisting of acrylamide (AM), 2-acrylamide-2-methylpropanesulfonic acid (AMPS), diallyl dimethyl ammonium chloride (DMDAAC), styrene (St) was named ASDS. ASDS was characterized by Fourier Transform Infrared (FT-IR), thermogravimetric analysis (TGA), particle size distribution, and transmission electron microscopy (TEM). The rheological property and filtration performance of ASDS in various temperature conditions were evaluated by rheological and filtration performance tests, respectively. The experimental results demonstrated that ASDS was smooth and malleable with a median particle size distribution of 1720 nm, and it exhibited good thermal stability with an initial thermal decomposition temperature of up to 316.9 °C. The ASDS maintains persistent plugging performance up to high temperatures of 180 °C for various pore sizes of filter medium. This resulted in a 56.6% reduction in filtration loss with filter paper and a reduction from 122 mL to 60 mL with ceramic sand disks under 180 °C 3.5 Mpa. This paper presents a preparation method for a plugging agent with good plugging performance in high-temperature conditions, which has potential applications in water-based drilling fluids.
研究领域:
石油工程
·
材料科学
✓ 已验证
产品关联
DOI
Nanomaterials
·
2019
·Vol. 9
·期 12
·1683
·
IF 4.034
Lan Ma,Pingya Luo,Yi He,Liyun Zhang,Yi Fan,Zhenju Jiang
Owing to the harsh downhole environments, poor dispersion of silica at high salinity and high temperature can severely restrict its application as the nano-plugging agent in shale gas exploitation. The objective of this study is to improve salt tolerance and thermal stability of silica. Herein, silica was successfully functionalized with an anionic polymer (p SPMA) by SI-ATRP (surface-initiated atom transfer radical polymerization), named SiO2-g-SPMA. The grafted pSPMA brushes on silica provided sufficient electrostatic repulsion and steric repulsion for stabilizing silica in a harsh environment. The modified silica (SiO2-g-SPMA) had excellent colloidal stability at salinities up to 5.43 M NaCl (saturated brine) and standard API brine (8 wt% NaCl + 2 wt% CaCl2) for 30 days at room temperature. Simultaneously, the SiO2-g-SPMA was stable at 170 °C for 24 h as well as stable in weakly alkali environment. Furthermore, the plugging performance of SiO2-g-SPMA in water-based drilling fluids for low permeate reservoir reached to 78.25% when adding a small amount of 0.5 wt% SiO2-g-SPMA, which effectively hindered the water invasion into formation and protected the reservoir.Keywords:silica;SI-ATRP;anionic polymers;brine stability;nano-plugging additive
研究领域:
石油工程
·
材料科学
✓ 已验证
DOI
PubMed
高影响因子
Frontiers in Chemistry
·
2020
·
IF 3.693
Li He,Lv Kaihe,Huang Xianbin,Lu Zhen,Dong Xiaodong
Nanoscale plugging agent is essential to wellbore stability of troublesome shale formation in the drilling of oil and gas wells. In this paper, polymeric nanospheres (PNS) with a double cross-linked structure were synthesized using monomers of styrene (ST), acrylamide (AM), 2-Acrylamide- 2-methylpropanesulfonic acid (AMPS), and dimethyl diallyl ammonium chloride (DMDAAC). PNS were characterized by FTIR, SEM and TGA. The plugging performance of PNS was analyzed using nitrogen adsorption experiments and SEM. And compatibility with water based drilling fluid (WBM) was studied. Experimental results showed that PNS had a mean particle size of 133 nm, and could retain about half of the original size after high temperature treatment under 150–200°C. TGA showed that the initial decomposition temperature of PNS is around 315°C. After plugging by PNS, both the specific surface area and pore volume of the shale cuttings decreased substantially compared with those of shale samples treated with water. Thus, PNS was thermal stable in WBM under high temperature and could effectively plug shale pores. Besides, PNS was beneficial to reduce both API and HTHP fluid loss of WBM.
研究领域:
材料科学
·
化学工程
·
石油工程
✓ 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）