The Synthesis of Polymeric Nanospheres and the Application as High-Temperature Nano-Plugging Agent in Water Based Drilling Fluid

Li, He; Lv, Kaihe; Huang, Xianbin; Lu, Zhenjiang; Dong, Xiaodong

doi:10.3389/fchem.2020.00247

Cited by 30 publications

(32 citation statements)

References 34 publications

(37 reference statements)

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“…Good plugging performance for nanoscale pores can affect the properties of shale itself, such as reducing the pore volume and specific surface area of shale (Li et al 2020a;Qiu et al 2018). The recovered shale fragments before and after the shale recovery test were used for the nitrogen adsorption experiment.…”

Section: Nitrogen Adsorption Testmentioning

confidence: 99%

“…The hydration of shale would lead to increases in surface area and pore volume (Li et al 2020a;Qiu et al 2018), so water-treated shale samples obtained the largest surface area and pore volume. While laponite-treated shale samples had a lower surface area and pore volume than the water-treated shale, which was due to good inhibition property and plugging performances of laponite.…”

Section: Plugging Performancementioning

confidence: 99%

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Laponite: a promising nanomaterial to formulate high-performance water-based drilling fluids

et al. 2020

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High-performance water-based drilling fluids (HPWBFs) are essential to wellbore stability in shale gas exploration and development. Laponite is a synthetic hectorite clay composed of disk-shaped nanoparticles. This paper analyzed the application potential of laponite in HPWBFs by evaluating its shale inhibition, plugging and lubrication performances. Shale inhibition performance was studied by linear swelling test and shale recovery test. Plugging performance was analyzed by nitrogen adsorption experiment and scanning electron microscope (SEM) observation. Extreme pressure lubricity test was used to evaluate the lubrication property. Experimental results show that laponite has good shale inhibition property, which is better than commonly used shale inhibitors, such as polyamine and KCl. Laponite can effectively plug shale pores. It considerably decreases the surface area and pore volume of shale, and SEM results show that it can reduce the porosity of shale and form a seamless nanofilm. Laponite is beneficial to increase lubricating property of drilling fluid by enhancing the drill pipes/wellbore interface smoothness and isolating the direct contact between wellbore and drill string. Besides, laponite can reduce the fluid loss volume. According to mechanism analysis, the good performance of laponite nanoparticles is mainly attributed to the disk-like nanostructure and the charged surfaces.

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Section: Nitrogen Adsorption Testmentioning

confidence: 99%

Section: Plugging Performancementioning

confidence: 99%

Laponite: a promising nanomaterial to formulate high-performance water-based drilling fluids

et al. 2020

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“…However, these plugging agents are too large to effectively plug nanoscale pores. 18 Considering the size match, according to many studies, nanoscale plugging agents are critical for wellbore stability in troubled formations. 25 …”

Section: Introductionmentioning

confidence: 99%

“…However, the plugging agent has a great influence on the rheological properties of the drilling fluid, and it is difficult to meet the technical requirements of the drilling fluid for the performance. 18 Ma et al (2019) used acrylamide, 2-acrylamido-2-methyl-1-propanesulfonic acid, N -vinylpyrrolidone, and modified nanosilica as raw material, the copolymer (PAAN-SiO 2 ) was synthesized, and it can resist high temperature of 180 °C, which can significantly reduce shale permeability, prevent fluid intrusion, and improve wellbore stability. However, the size of the plugging agent is large and cannot effectively plug the nanopores and seams.…”

Section: Introductionmentioning

confidence: 99%

“…However, shale formations are mostly developed with natural pores and fractures, during the development of shale gas, there is still drilling fluid filtrate infiltrating into shale pores and fractures, , which weakens the structural force of the wellbore and causes the instability problem; − therefore, in order to improve the wellbore stability, it is necessary to strengthen the ability of water-based drilling fluid to plug microfractures. − Adding effective nano-plugging materials to drilling fluids is the key to solving the problem of shale wellbore instability. , There is a wide range of existing plugging agents, including ultra-fine calcium carbonate, fibers, asphalts, polymers, gel particles, and so forth. However, these plugging agents are too large to effectively plug nanoscale pores . Considering the size match, according to many studies, nanoscale plugging agents are critical for wellbore stability in troubled formations …”

Section: Introductionmentioning

confidence: 99%

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Preparation of the Tetrameric Poly(VS-St-BMA-BA) Nano-Plugging Agent and Its Plugging Mechanism in Water-Based Drilling Fluids

et al. 2022

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In response to the current problem that micron-scale plugging agents cannot effectively plug shale nanopores and fractures, tetrameric poly(VS-St-BMA-BA) nanoparticles were synthesized by the Michael addition reaction using sodium vinyl sulfonate, styrene, butyl methacrylate, and butyl acrylate as raw materials. The nanoparticles poly(VS-St-BMA-BA) were characterized by infrared spectroscopy, particle size analysis, and thermogravimetric analysis. The particle size distribution of poly(VS-St-BMA-BA) at room temperature ranged from 62.17 to 96.44 nm, with a median particle size of 75.8 nm, and could withstand high temperature of 359.5 °C. The effects of poly(VS-St-BMA-BA) on the rheological parameters of drilling fluid and the effects of different temperatures on the median particle size were investigated by the drilling fluid performance testing methods and high-temperature stability testing methods. The results showed that the apparent viscosity, plastic viscosity, yield point, and high temperature and high pressure water loss of drilling fluid gradually decreased with the increase in poly(VS-St-BMA-BA) dosage; when the addition of poly(VS-St-BMA-BA) was 2.0%, the overall performance of drilling fluid was better, the filtration loss was 4.4 mL, and the drilling fluid had good water loss wall building performance. The median particle size of poly(VS-St-BMA-BA) was 132.60 nm (the particle size at room temperature was 75.8 nm) after standing for 16 h at 180 °C, indicating that poly(VS-St-BMA-BA) has good high-temperature stability and dispersion stability. The plugging performance and plugging mechanism of poly(VS-St-BMA-BA) under extreme conditions (high temperature) were investigated by the plugging performance test method and pressure transfer method. The results showed that the plugging rate of artificial mud cake and artificial core reached 48.18 and 88.75%, respectively, when the amount of poly(VS-St-BMA-BA) was added at 2.0%. In the pressure-transfer experiments, poly(VS-St-BMA)-BA) could invade the 2 mm position of the nanopore fracture on the core surface and form a sealing barrier layer to prevent the further invasion of liquid. Combined with the pressure-transfer experiment, it shows that poly(VS-St-BMA-BA) can enter the nanopore and fracture at a certain distance under the action of formation pressure and keep accumulating to form a tight blockage, which can effectively prevent the filtrate from entering the nanopore fracture of the shale formation. Poly(VS-St-BMA-BA) is expected to be used as a promising nano-plugging agent in water-based drilling fluids.

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Study on self‐healing gel plugging agent based on non‐covalent bonding interaction for drilling fluid

Zhou

Ren

et al. 2023

J of Applied Polymer Sci

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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.

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The Synthesis of Polymeric Nanospheres and the Application as High-Temperature Nano-Plugging Agent in Water Based Drilling Fluid

Cited by 30 publications

References 34 publications

Laponite: a promising nanomaterial to formulate high-performance water-based drilling fluids

Laponite: a promising nanomaterial to formulate high-performance water-based drilling fluids

Preparation of the Tetrameric Poly(VS-St-BMA-BA) Nano-Plugging Agent and Its Plugging Mechanism in Water-Based Drilling Fluids

Study on self‐healing gel plugging agent based on non‐covalent bonding interaction for drilling fluid

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