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Journal articles on the topic 'Shale inhibition'

Author: Grafiati

Published: 4 June 2021

Last updated: 1 February 2022

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1

Du, Weichao, Xiangyun Wang, Gang Chen, Jie Zhang, and Michal Slaný. "Synthesis, Property and Mechanism Analysis of a Novel Polyhydroxy Organic Amine Shale Hydration Inhibitor." Minerals 10, no. 2 (January 31, 2020): 128. http://dx.doi.org/10.3390/min10020128.

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Based on the adsorption mechanism analysis of polyhydroxy organic compound on a shale surface, a novel polyhydroxy organic amine shale hydration inhibitor N, N, N′, N′-tetrakis (2-hydroxyethyl) ethylenediamine (THEED) was synthesized via a nucleophilic reaction by using diethanolamine and dibromoethane as raw materials. Its structure was characterized by Fourier transform infrared spectrometry (FTIR), Hydrogen Nuclear Magnetic Resonance (1H NMR) and Liquid Chromatography Mass Spectrometry (LCMS). The inhibition performance of THEED was studied by a shale rolling recovery experiment, a linear expansion experiment and the particle size distribution experiment. Results showed the shale rolling recovery rate in 2.0 wt % THEED solutions was up to 89.6% at the rolling condition of 100 °C × 16 h, and the linear expansion height of artificial shale core in 2.0 wt % THEED solutions was just 4.74 mm after 16 h. The average particle size of Na-bentonite (Na-MMT) in fresh water was 8.05 μm, and it was observed that the average particle size has been increased to 124 μm in 2.0 wt % THEED solutions. The shale hydration inhibition mechanism of the novel inhibitor THEED was analyzed by FTIR, Scanning Electron Microscopy (SEM) and X-ray diffractometry (XRD), we concluded that the nice shale hydration inhibition performance of THEED was achieved by means of intercalation and adsorption onto the surface of shale. The superior shale hydration inhibition property makes THEED promising in maintaining wellbore stability in drilling engineering.

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2

Parvizi Ghaleh, Saeed, Elnaz Khodapanah, and Seyyed Alireza Tabatabaei-Nezhad. "Experimental evaluation of thiamine as a new clay swelling inhibitor." Petroleum Science 17, no. 6 (June 1, 2020): 1616–33. http://dx.doi.org/10.1007/s12182-020-00466-6.

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AbstractThis study aims at evaluating the performance of thiamine as a new eco-friendly shale inhibitor in water-based drilling fluids (WBDFs). The evaluation experiments include sedimentation, bentonite inhibition, filtration, zeta potential, thermal gravimetric analysis, scanning electron microscopy, X-ray diffraction, shale cuttings recovery, linear swelling and Fourier transform infrared spectroscopy (FTIR). The performance of thiamine was compared to potassium chloride. In contrast to deionized water, the aqueous solution of thiamine exhibited greater power to inhibit montmorillonite (Mt) dispersion, much more Mt loading capacity (280 g/L) and fluid loss, lower Mt mass loss, larger aggregated Mt particles, lower interlayer space of the Mt particles, less shale cuttings disintegration and lower linear swelling. Adsorption of thiamine on Mt led to a significant shift in the value of zeta potential (from −17.1 to +8.54 mV). Thiamine demonstrated superior inhibitive performance than potassium chloride. FTIR analysis confirmed that thiamine is adsorbed on Mt particles. The compatibility test revealed the compatibility of thiamine with conventional WBDF additives. It was concluded that the main probable inhibition mechanisms of thiamine are the cation exchange and Mt surface coating. In view of its prominent inhibition capacity and great environmental acceptability, thiamine is a promising inhibitor for drilling in water-sensitive formations.

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3

Zhong, Hanyi, Dong Sun, Weian Huang, Yunfeng Liu, and Zhengsong Qiu. "Effect of Cycloaliphatic Amine on the Shale Inhibitive Properties of Water-Based Drilling Fluid." Open Fuels & Energy Science Journal 8, no. 1 (January 22, 2015): 19–27. http://dx.doi.org/10.2174/1876973x01508010019.

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In order to improve the inhibitive properties and high temperature resistance of shale inhibitor, cycloaliphatic amines were introduced as shale hydration inhibitors in water-based drilling fluids. Bulk hardness test, shale cuttings dispersion test, bentonite inhibition test and water adsorption test were carried out to characterize the inhibitive properties of the novel amines. Surface tension measurement, zeta potential measurement, XRD, contact angle test, SEM and TGA were performed to investigate the interaction between the cycloaliphatic amines and clay particles. The results indicated that cycloaliphatic amines exhibited superior inhibitive properties to the state of the art inhibitors. Moreover, the amines were high temperature resistant. The hydrophobic amine could intercalate into the clay gallery with monolayer orientation. The protonated ammonium ions neutralized the negatively charged surface. After adsorption, the hydrophobic segment covered the clay surface and provided a shell preventing the ingress of water.

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4

Zhang, Yayun, and Cong Xiao. "Molecular Dynamics Simulation of Clay Hydration Inhibition of Deep Shale." Processes 9, no. 6 (June 19, 2021): 1069. http://dx.doi.org/10.3390/pr9061069.

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In the process of the exploitation of deep oil and gas resources, shale wellbore stability control faces great challenges under complex temperature and pressure conditions. It is difficult to reflect the micro mechanism and process of the action of inorganic salt on shale hydration with the traditional experimental evaluation technology on the macro effect of restraining shale hydration. Aiming at the characteristics of clay minerals of deep shale, the molecular dynamics models of four typical cations (K+, NH4+, Cs+ and Ca2+) inhibiting the hydration of clay minerals have been established by the use of the molecular dynamics simulation method. Moreover, the micro dynamics mechanism of typical inorganic cations inhibiting the hydration of clay minerals has been systematically evaluated, as has the law of cation hydration inhibition performance in response to temperature, pressure and ion type. The research indicates that the cations can promote the contraction of interlayer spacing, compress fluid intrusion channels, reduce the intrusion ability of water molecules, increase the negative charge balance ability and reduce the interlayer electrostatic repulsion force. With the increase in temperature, the inhibition of the cations on montmorillonite hydration is weakened, while the effect of pressure is opposite. Through the molecular dynamics simulation under different temperatures and pressures, we can systematically understand the microcosmic dynamics mechanism of restraining the hydration of clay in deep shale and provide theoretical guidance for the microcosmic control of clay hydration.

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5

Deng, Qiang, Deng Feng Wei, Zheng Qin Ye, and Jin Fang Xu. "Preparation and Swelling Inhibition of Polyammonium." Advanced Materials Research 482-484 (February 2012): 1317–20. http://dx.doi.org/10.4028/www.scientific.net/amr.482-484.1317.

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A new anti-swelling agent was synthesized by polymerizing epichlorohydrin and dimethyl amine polymer. The swelling inhibition properties were investigated over clay and shale. It was found that the clay inhibition of swelling properties was greatly enhanced compared with common inorganic salts. However, to shale, the swelling properties did not inhibited efficiently by using prepared polymers. Furthermore, the influence of cross linking of polyammonium to the swelling ability of prepared polymer has been also carried out by using triethylenetetramine cross linking agent. In the case of shale, the swelling inhibit properties was improved after cross link, while opposite swelling effect was observed over clay.

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6

Chenevert, M. E., and S. O. Osisanya. "Shale/Mud Inhibition Defined With Rig-Site Methods." SPE Drilling Engineering 4, no. 03 (September 1, 1989): 261–68. http://dx.doi.org/10.2118/16054-pa.

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7

Fujii, Rui. "Hundred years' history of challenge to shale inhibition." Journal of the Japanese Association for Petroleum Technology 82, no. 5 (2017): 332–45. http://dx.doi.org/10.3720/japt.82.332.

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8

Sun, Jinsheng, Fan Zhang, Kaihe Lv, and Xiaofeng Chang. "A novel film-forming silicone polymer as shale inhibitor for water-based drilling fluids." e-Polymers 19, no. 1 (November 3, 2019): 574–78. http://dx.doi.org/10.1515/epoly-2019-0061.

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AbstractA novel shale inhibitor was synthesized by free radical copolymerization in aqueous solution, using acrylic acid (AA), acrylamide (AM), maleic anhydride (MA) KH-570 as reaction monomers and potassium persulfate as initiator. The structure of the copolymer was characterized by Fourier transform infrared spectroscopy (FT-IR). Thermogravimetric analysis (TGA) showed that the thermal decomposition temperature of the copolymer was higher than 226°C, which indicated that the copolymer had good high temperature resistance. At the same time, the inhibition performance of the copolymer was further evaluated by linear expansion, immersion test and rolling recovery. The experimental results show that the inhibition performance of organosilicon polymer is obviously better than that of potassium chloride (KCl) and potassium polyacrylate (KPAM), and it can be used as an inhibitor in shale gas drilling.

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9

Zhang, Jie, Weimin Hu, Li Zhang, Tiehu Li, Dan Cai, and Gang Chen. "Investigation of ammonium–lauric salt as shale swelling inhibitor and a mechanism study." Adsorption Science & Technology 37, no. 1-2 (November 1, 2018): 49–60. http://dx.doi.org/10.1177/0263617418809832.

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In this work, a series of ammonium–lauric salts (ALS) was prepared with lauric acid and amines as small molecular shale swelling inhibitor. The inhibitors were screened by the linear expansion test first, and the result shows that the inhibitor prepared by lauric acid and diethylenetriamine with the mole ratio of 2:1 (ALS-2) displays excellent inhibition effect on the hydration expansion of bentonite. The inhibition of ALS-2 to bentonite was fully evaluated by various methods in the following work, including clay linear swelling test and particle distribution measurement. The results show that ALS-2 has superior performance to inhibit the hydration swelling and dispersion of bentonite, and the swelling rate of bentonite in 0.5% ALS-2 was reduced to 29.7%. In water-based drilling fluid, ALS-2 is compatible with the conventional additives, and it can improve the lubricity of the mud cake obviously after aged under 120°C. Besides, it can control the particle size of bentonite in water. The inhibition mechanism of the ammonium–lauric salts was discussed in detail through physical adsorption, scanning electron microscopy, X-ray diffraction, thermogravimetric analysis, and Fourier transform infrared spectroscopy.

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10

Kim, Kyung Tae, Mantha Sai Pavan Jagannath, Gregory M. Su, Guillaume Freychet, Tongzhou Zeng, Kishore K. Mohanty, Graeme Henkelman, Lynn E. Katz, and Charles J. Werth. "Surfactant inhibition mechanisms of carbonate mineral dissolution in shale." Colloids and Surfaces A: Physicochemical and Engineering Aspects 625 (September 2021): 126857. http://dx.doi.org/10.1016/j.colsurfa.2021.126857.

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11

BARATI, Pezhman, Sadegh KESHTKAR, Amirhossein AGHAJAFARI, Khalil SHAHBAZI, and Ali MOMENI. "Inhibition performance and mechanism of Horsetail extract as shale stabilizer." Petroleum Exploration and Development 43, no. 3 (June 2016): 522–27. http://dx.doi.org/10.1016/s1876-3804(16)30061-1.

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12

Hamdan, M. A., and A. Qubbaj. "Inhibition effect of inert compounds on oil shale dust explosion." Applied Thermal Engineering 18, no. 5 (January 1998): 221–29. http://dx.doi.org/10.1016/s1359-4311(97)00085-9.

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13

Zhang, Lei, Xiaoming Wu, Yujie Sun, Jihua Cai, and Shuaifeng Lyu. "Experimental study of the pomelo peel powder as novel shale inhibitor in water-based drilling fluids." Energy Exploration & Exploitation 38, no. 2 (October 11, 2019): 569–88. http://dx.doi.org/10.1177/0144598719882147.

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The hydration and swelling of shale is a persistent challenge in the drilling of oil and gas wells. Many methods of reducing shale hydration and swelling have been developed; however, most of them are high-cost or release pollutants. In this study, we explored the use of pomelo peel powder as a novel additive to water-based drilling fluids for inhibiting shale hydration swelling in an environmentally sustainable manner. We compared the performance of the drilling fluid containing pomelo peel powder to that of traditional shale inhibitors, such as potassium chloride and polyamine. Moreover, hydration inhibition, bentonite precipitation dynamic linear expansion, rolling recovery, and adsorption experiments were conducted to investigate the inhibitory effects of the pomelo peel powder on shale. The results show that the pomelo peel powder solution with a mass fraction of 1% and an optimised particle size of over 160 mesh was acidic, could prevent shale collapse, and could reduce mud loss by filtration. The rolling recovery of shale cuttings reached 95% with the addition of pomelo peel powder, and the powder could also inhibit the hydration of bentonite, prevent clay minerals from dispersing in a solution, and reduce the expansion of bentonite. The inhibitory effect of the powder was slightly worse than that of potassium chloride and polyamine; however, the difference was not significant. The anti-swelling mechanism of pomelo peel powder was then analysed, and we found that fresh pomelo peel powder contains a high number of active substances that reduce the filtration of mud, improve its rheological properties, and hinder the hydration and expansion of clay. Pomelo peel is available worldwide and is easy to obtain as a shale inhibitor. Thus, using pomelo peel powder can effectively alleviate ecological pressure and reduce environmental pollution.

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14

Fu, Lipei, Kaili Liao, Jijiang Ge, Yanfeng He, Weiqiu Huang, and Erdeng Du. "Preparation and inhibition mechanism of bis-quaternary ammonium salt as shale inhibitor used in shale hydrocarbon production." Journal of Molecular Liquids 309 (July 2020): 113244. http://dx.doi.org/10.1016/j.molliq.2020.113244.

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15

Qiu, Zhengsong, Jiangen Xu, Peng Yang, Xin Zhao, Tingbo Mou, Hanyi Zhong, and Weian Huang. "Effect of Amphiphilic Polymer/Nano-Silica Composite on Shale Stability for Water-Based Muds." Applied Sciences 8, no. 10 (October 7, 2018): 1839. http://dx.doi.org/10.3390/app8101839.

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Research on using nanotechnology to solve shale instability problems in drilling engineering has been increasing. The combination of amphiphilic polymer and silica nanoparticles may be a new way to improve shale stability. Herein, an amphiphilic polymer/nano-silica composite (poly(styrene-methyl methacrylate-acrylamide)/nano-SiO2) was introduced as a novel shale stabilizer SMA/SiO2 for water-based muds, which possessed the advantages of both physical plugging and chemical inhibition during the drilling operations. The SMA/SiO2 was prepared and characterized by Fourier transform infrared spectra (FT-IR), nuclear magnetic resonance (1H-NMR), transmission electron microscope (TEM), particle size distribution (PSD) and thermogravimetric analysis (TGA) experiments, which confirmed that SMA/SiO2 was regularly spherical with nano-scale and showed good high-temperature resistance. To evaluate the plugging capacity of SMA/SiO2, the pressure transmission test and BET analysis were applied. The results indicated SMA/SiO2 was capable of effectively plugging the pores and fractures in shale. To evaluate the hydration inhibition capacity of SMA/SiO2, the rolling dispersion experiment and contact angle test were adopted. The results demonstrated that SMA/SiO2 could reduce the tendency of shale hydration, which was better than potassium chloride (KCl) and polymeric alcohol (JHC). In addition, SMA/SiO2 only created slight variations on the rheological parameters of the water-based muds (WBMs) and showed a significant filtration control performance. Due to the outstanding performance of physical plugging and chemical inhibition, SMA/SiO2 was expected to be a novel shale stabilizer to solve shale instability problems.

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16

Ballerstedt, Hendrik, Eva Pakostova, D. Barrie Johnson, and Axel Schippers. "Approaches for Eliminating Bacteria Introduced during In Situ Bioleaching of Fractured Sulfidic Ores in Deep Subsurface." Solid State Phenomena 262 (August 2017): 70–74. http://dx.doi.org/10.4028/www.scientific.net/ssp.262.70.

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The major objective of the EU Horizon 2020 project “BioMOre” is the technical realization of indirect in situ leaching of Kupferschiefer sandstone and black shale ore by a ferric iron lixiviant generated by a mixed culture of autotrophic, acidophilic, iron-oxidizing bacteria and archaea in a ferric iron-generating bioreactor (FIGB). These organisms could colonize the deeply buried geological formations even under anaerobic conditions as most are able to grow by coupling the reduction of ferric iron to the oxidation of reduced sulfur compounds in the absence of oxygen. Development of an inhibition protocol to eliminate these allochthonous microbial bioreactor populations subsequent to the completion of in situ bioleaching was therefore investigated. Column bioleaching experiments using a laboratory-scale FIGB confirmed not only that metals were solubilised from both the sandstone and shale ores, but also that significant numbers of bacteria were released from the FIGB. The efficacy of 13 different chemical compounds in inhibiting microbial iron oxidation has been tested at different concentrations in shake flask and FIGB-coupled columns. Iron-oxidation activity, microcalorimetrically-determined activity and ATP measurements, in combination with microscopic cell counts and biomolecular analysis (T-RFLP, qPCR), plate counts and most-probable-number (MPN), were used to monitor the inhibiting effects on the acidophiles. Complete inhibition of metabolic activity of iron-oxidizing acidophiles was achieved in the presence of 0.4 mM formate, 300 mM chloride, 100 mM nitrate, 10 mM of primary C6 to C8 alcohols, 100 mM 1-butanol, 100 mM 1-pentanol, 0.1 mM SDS or 0.35 mM benzoic acid. No inhibition was found for 0.6 mM acetic acid and 200 mM methanol. Based on these results a recipe for the chemical composition of the “decommissioning solution” is proposed.

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17

An, Yuxiu, and Peizhi Yu. "A strong inhibition of polyethyleneimine as shale inhibitor in drilling fluid." Journal of Petroleum Science and Engineering 161 (February 2018): 1–8. http://dx.doi.org/10.1016/j.petrol.2017.11.029.

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18

Wilson, M. J., and L. Wilson. "Clay mineralogy and shale instability: an alternative conceptual analysis." Clay Minerals 49, no. 2 (April 2014): 127–45. http://dx.doi.org/10.1180/claymin.2014.049.2.01.

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AbstractThe instability of shales in drilled formations leads to serious operational problems with major economic consequences for petroleum exploration and production. It is generally agreed that the nature of the clay minerals in shale formations is a primary causative factor leading to their instability, although the exact mechanism involved is more debateable. Currently, the principal cause of shale instability is considered to be volume expansion following the osmotic swelling of Nasmectite. However, illitic and kaolinitic shales may also be unstable, so that interlayer expansion cannot therefore be considered as a universal causative mechanism of shale instability. This review considers alternative scenarios of shale instability where the major clay minerals are smectite, illite, mixed-layer illite-smectite (I/S) and kaolinite respectively. The influence of interacting factors that relate to shale clay mineralogy such as texture, structure and fabric are discussed, as are the pore size distribution and the nature of water in clays and shales and how these change with increasing depth of burial. It is found from the literature that the thickness of the diffuse double layer (DDL) of the aqueous solutions associated with the charged external surfaces of clay minerals is probably of the same order or even thicker than the sizes of a significant proportion of the pores found in shales. In these circumstances, overlap of the DDLs associated with exposed outer surfaces of clay minerals on opposing sides of micropores (<2 nm in diameter) and mesopores (2–50 nm in diameter) in a lithostatically compressed shale would bring about electrostatic repulsion and lead to increased pore/ hydration pressure in smectitic, illitic and even kaolinitic shales. This pressure would be inhibited by the use of more concentrated K-based fluids which effectively shrink the thickness of the DDL towards the clay mineral surfaces in the pore walls. The use of soluble polymers would also encapsulate these clay mineral surfaces and so inhibit their hydration. In this scenario, the locus of action with respect to shale instability and its inhibition is moved from the interlamellar space of the smectitic clays to the charged external surfaces of the various clay minerals bounding the walls of the shale pores.

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19

Gou, Shaohua, Ting Yin, Qiang Xia, and Qipeng Guo. "Biodegradable polyethylene glycol-based ionic liquids for effective inhibition of shale hydration." RSC Advances 5, no. 41 (2015): 32064–71. http://dx.doi.org/10.1039/c5ra02236c.

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20

Chen, Shuya, Yanping Shi, Xianyu Yang, Kunzhi Xie, and Jihua Cai. "Design and Evaluation of a Surfactant–Mixed Metal Hydroxide-Based Drilling Fluid for Maintaining Wellbore Stability in Coal Measure Strata." Energies 12, no. 10 (May 16, 2019): 1862. http://dx.doi.org/10.3390/en12101862.

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Co-exploitation of coal measure gases (coalbed gas, shale gas, and tight sandstone gas) puts a higher requirement on drilling fluids. Conventional drilling fluids have disadvantages, such as causing problems of borehole collapse, formation damage, and water blockage. This paper proposes a set of high inhibitive and low-damage drilling fluids that function by electrical inhibition and neutral wetting. Zeta potential results showed that the negative electrical property of Longtan coal in Bijie, Guizhou, can be reversed by organic mixed metal hydroxide (MMH) and the cationic surfactant alkyl trimethylammonium bromide (CS-5) from −3.63 mV to 19.75 mV and 47.25 mV, respectively. Based on the contact angle and Fourier Transform Infrared Spectroscopy (FT-IR) results, it can be concluded that chemical adsorption dominates between the Longmaxi shale and surfactants, and physical adsorption between the Longtan coal and surfactants. A compound surfactant formula (0.001 wt% CS-4 + 0.001 wt% CS-1 + 0.001 wt% CS-3), which could balance the wettability of the Longmaxi shale and the Longtan coal, making them both appear weakly hydrophilic simultaneously, was optimized. After being treated by the compound surfactants, the contact angles of the Longmaxi shale and the Longtan coal were 89° and 86°, respectively. Pressure transmission tests showed that the optimized combination of compound surfactants and inorganic MMH (MMH-1) could effectively reduce permeability of the Longmaxi shale and the Longtan coal, thus retarding pore pressure transmission in coal measure strata. Then, the proposed water-based drilling fluid (WBDF) system (4 wt% sodium bentonite + 1.5 wt% sodium carboxymethyl cellulose + 2 wt% lignite resin + 5 wt% potassium chloride + 3 wt%MMH-1 + 0.001 wt% CS-4 + 0.001 wt% CS-1 + 0.001 wt% CS-3) was evaluated based on parameters including rheology, American Petroleum Institute (API) filtration, electrical property, wettability, inhibition capability, reservoir protection characteristics, and anti-pollution performance. It had an API filtration of 7 mL, reservoir damage rate of 10%, moderate and acceptable viscosity, strong inhibition capability to coal measure strata rocks, good tolerance to inorganic pollutants and drilling cuttings, and environmentally friendly properties. It could meet wellbore stability and reservoir protection requirements in the co-exploitation of coal measure gases.

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21

Palumbo, Gaetano, Marcin Górny, and Jacek Banaś. "Corrosion Inhibition of Pipeline Carbon Steel (N80) in CO2-Saturated Chloride (0.5 M of KCl) Solution Using Gum Arabic as a Possible Environmentally Friendly Corrosion Inhibitor for Shale Gas Industry." Journal of Materials Engineering and Performance 28, no. 10 (October 2019): 6458–70. http://dx.doi.org/10.1007/s11665-019-04379-3.

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Abstract The inhibition effect of gum arabic (GA) was investigated using weight loss measurements and electrochemical techniques. The results show that the inhibition efficiency of GA increased with an increase in the concentration of the inhibitor but decreased with the temperature. Immersion time was found to have a profound effect on the corrosion inhibition performance of the inhibitor. Polarization measurements revealed that GA was a mixed-type inhibitor, with higher influence on the anodic reaction. The inhibitor followed the Temkin’s adsorption isotherm, and the values of the standard free adsorption energy indicate a mixed-type adsorption, with the physical adsorption being more dominant. SEM–EDS and FT-IR measurements were also employed to support the findings.

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22

Ali, Muhammad, Husna Hayati Jarni, Adnan Aftab, Abdul Razak Ismail, Noori M. Cata Saady, Muhammad Faraz Sahito, Alireza Keshavarz, Stefan Iglauer, and Mohammad Sarmadivaleh. "Nanomaterial-Based Drilling Fluids for Exploitation of Unconventional Reservoirs: A Review." Energies 13, no. 13 (July 2, 2020): 3417. http://dx.doi.org/10.3390/en13133417.

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The world’s energy demand is steadily increasing where it has now become difficult for conventional hydrocarbon reservoir to meet levels of demand. Therefore, oil and gas companies are seeking novel ways to exploit and unlock the potential of unconventional resources. These resources include tight gas reservoirs, tight sandstone oil, oil and gas shales reservoirs, and high pressure high temperature (HPHT) wells. Drilling of HPHT wells and shale reservoirs has become more widespread in the global petroleum and natural gas industry. There is a current need to extend robust techniques beyond costly drilling and completion jobs, with the potential for exponential expansion. Drilling fluids and their additives are being customized in order to cater for HPHT well drilling issues. Certain conventional additives, e.g., filtrate loss additives, viscosifier additives, shale inhibitor, and shale stabilizer additives are not suitable in the HPHT environment, where they are consequently inappropriate for shale drilling. A better understanding of the selection of drilling fluids and additives for hydrocarbon water-sensitive reservoirs within HPHT environments can be achieved by identifying the challenges in conventional drilling fluids technology and their replacement with eco-friendly, cheaper, and multi-functional valuable products. In this regard, several laboratory-scale literatures have reported that nanomaterial has improved the properties of drilling fluids in the HPHT environment. This review critically evaluates nanomaterial utilization for improvement of rheological properties, filtrate loss, viscosity, and clay- and shale-inhibition at increasing temperature and pressures during the exploitation of hydrocarbons. The performance and potential of nanomaterials, which influence the nature of drilling fluid and its multi-benefits, is rarely reviewed in technical literature of water-based drilling fluid systems. Moreover, this review presented case studies of two HPHT fields and one HPHT basin, and compared their drilling fluid program for optimum selection of drilling fluid in HPHT environment.

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23

Shenoy, Sudhir S., Terence Gilmore, Allan J. Twynam, Arvind D. Patel, Stephen D. Mason, Gregory Kubala, Benoit Vidick, and Mehmet Parlar. "Guidelines for Shale Inhibition During Openhole Gravel Packing With Water-Based Fluids." SPE Drilling & Completion 23, no. 02 (June 1, 2008): 80–87. http://dx.doi.org/10.2118/103156-pa.

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24

Ibrahim, Mukaila A., and Tawfik A. Saleh. "Synthesis of efficient stable dendrimer-modified carbon for cleaner drilling shale inhibition." Journal of Environmental Chemical Engineering 9, no. 1 (February 2021): 104792. http://dx.doi.org/10.1016/j.jece.2020.104792.

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25

Beg, Mukarram, Priyanka Singh, Shivanjali Sharma, and Umaprasana Ojha. "Shale inhibition by low-molecular-weight cationic polymer in water-based mud." Journal of Petroleum Exploration and Production Technology 9, no. 3 (November 29, 2018): 1995–2007. http://dx.doi.org/10.1007/s13202-018-0592-7.

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26

Xu, Jian-gen, Zhengsong Qiu, Xin Zhao, Tingbo Mou, Hanyi Zhong, and Weian Huang. "A polymer microsphere emulsion as a high-performance shale stabilizer for water-based drilling fluids." RSC Advances 8, no. 37 (2018): 20852–61. http://dx.doi.org/10.1039/c8ra03492c.

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27

Ren, Xiaoxia, Ran Liu, and Zhe Ma. "Experimental investigation of a low-molecular-weight polymer coating agent for deep-sea oil and gas drilling." Journal of Petroleum Exploration and Production Technology 11, no. 7 (June 4, 2021): 2953–62. http://dx.doi.org/10.1007/s13202-021-01198-y.

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AbstractIn order to solve the problems due to the thickening of drilling fluids at low temperatures caused by the use of high-molecular-weight polymer coating agents in offshore deep-sea oil and gas drilling, a low-molecular-weight polymer coating agent named PADA was synthesized with acrylamide, methacryloxyethyltrimethyl ammonium chloride, and 2-acrylamido-2-methyl propane sulfonic acid. The PADA polymer was characterized with Fourier transform infrared spectroscopy and gel permeation chromatography. The shale inhibition effects of the PADA polymer and associated mechanisms were investigated by shale recovery and expansion experiments, transmission electron microscopy observation, particle size and zeta potential analysis, and interlayer spacing measurements. In addition, the effects of the coating agent on the filter cakes and the low temperature rheological properties of bentonite mud were also tested, and the polymer biodegradability was evaluated. The results showed that the molecular weight of the PADA polymer was 265,000 D, which was significantly lower than that of the traditional coating agents. The PADA had similar effects as two typical commercial products CAP and HPAM on inhibiting the hydration dispersion of shales and performed better than another product PAM. The inhibition effect was achieved by the polymer absorption onto the clay particles through both hydrogen bonding and the electrostatic interactions. The viscosity of bentonite mud containing PADA was much lower than that of mud with other coating agents at 4 °C, so the serious thickening caused by traditional coating agents at a low temperature could be avoided. In addition, it is relatively easily biodegraded.

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28

Zhengqin, Ye, Ye Zhongbin, Huang Lei, Bai Yun, Li Lili, Zhang Jie, Qu Chentun, and Chen Gang. "Preparation and Application of a New Crosslinked Polyammonium as a Shale Inhibitor." Journal of Applied Biomaterials & Functional Materials 16, no. 1_suppl (January 2018): 119–24. http://dx.doi.org/10.1177/2280800017753054.

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Background: Despite the fact that a number of traditional shale inhibitors have been utilized widely in drilling operations, the same additive may be unfavorable for different drilling due to environmental protection requirements which limit scales of use. Hence, a series of polyammonium compounds was prepared from dimethylamine, epichlorohydrin, and melamine (DEM). Methods: To concentrate our efforts, we used both standard and extra methods to investigate the inhibitive properties of a melamine crosslinking agent using mud balls immersion tests, linear expansion measurements, laser particle distribution measurements, thermogravimetric analysis, and scanning electron microscopy. Results: The anti-swelling rate of DEM-8 reached up to 92.3% when its concentration reached 0.8%. DEM-8 has strong inhibitive capability to bentonite hydration swelling. DEM-8 can affect the bentonite particle size at a large scale. It may adsorb on the surface of clay through hydrogen bonds and electrostatic interaction by an anchoring effect and a hydrophobic effect. Conclusions: Compared with a blank solution, DEM-8 displays high inhibitive ability against the hydration and swelling of clay. The mud ball is more stable in DEM-8 solution and its swelling degree is very low compared with that of the control test. The inhibition mechanism of DEM-8 to shale can be deduced in that hydrogen bonding, ion exchange, and anchoring effect help to control the hydration and swelling.

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Yu, Pei Zhi. "Preparation and Performance of Wax Emulsionusing in Drilling Fluid." Applied Mechanics and Materials 552 (June 2014): 286–90. http://dx.doi.org/10.4028/www.scientific.net/amm.552.286.

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An O/W type paraffin wax emulsions was prepared using Tweenand Span emulsifiers, and liquid paraffin. The influences of temperature, HLB and surfactants concentration in particle size of paraffin wax emulsions were studied, as were the stability of paraffin wax emulsions. The application performances in drilling fluid of paraffin wax emulsions were researched with respect to artificial core line swelling and shale recovery. Results showed that the best conditions of preparation of emulsified wax: surfactants concentration was 5%, temperature was 50°Cand HLB was 10.1-10.5. It was found that paraffin wax emulsions possess strong inhibition ability for hydration, swelling and dispersing of clay and shale. The inhibition ability of paraffin wax emulsions enhanced with KCl.

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Cao, Han, Zheng Zhang, Ting Bao, Pinghe Sun, Tianyi Wang, and Qiang Gao. "Experimental Investigation of the Effects of Drilling Fluid Activity on the Hydration Behavior of Shale Reservoirs in Northwestern Hunan, China." Energies 12, no. 16 (August 16, 2019): 3151. http://dx.doi.org/10.3390/en12163151.

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The interaction between drilling fluid and shale has a significant impact on wellbore stability during shale oil and gas drilling operations. This paper investigates the effects of the drilling fluid activity on the surface and osmotic hydration characteristics of shale. Experiments were conducted to measure the influence of drilling fluid activity on surface wettability by monitoring the evolution of fluid-shale contact angles. The relationship between drilling fluid activity and shale swelling ratio was determined to investigate the osmotic hydration behavior. The results indicate that, with increasing drilling fluid activity, the fluid–shale contact angles gradually increase—the higher the activity, the faster the adsorption rate; and the stronger the inhibition ability, the weaker the surface hydration action. The surface adsorption rate of the shale with a KCl drilling fluid was found to be the highest. Regarding the osmotic hydration action on the shale, the negative extreme swelling ratio (b) of the shale was found to be: bKCl < bCTAB < bSDBS. Moreover, based on the relationship between the shale swelling ratio and drilling fluid activity, shale hydration can be divided into complete dehydration, weak dehydration, surface hydration, and osmotic hydration, which contributes to the choice of drilling fluids to improve wellbore stability.

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Ni, Xiaoxiao, Guancheng Jiang, Yiying Li, Lili Yang, Wuquan Li, Kai Wang, and Zhengqiang Deng. "Synthesis of superhydrophobic nanofluids as shale inhibitor and study of the inhibition mechanism." Applied Surface Science 484 (August 2019): 957–65. http://dx.doi.org/10.1016/j.apsusc.2019.04.167.

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Jiang, Wenchao, Zhongbin Ye, Shaohua Gou, Xiangjun Liu, Lixi Liang, Wan Wang, and Zewen Song. "Modularβ-cyclodextrin and polyoxyethylene ether modified water-soluble polyacrylamide for shale hydration inhibition." Polymers for Advanced Technologies 27, no. 2 (September 15, 2015): 213–20. http://dx.doi.org/10.1002/pat.3623.

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Wang, Hao, and Xiaolin Pu. "Structure and inhibition properties of a new amine-terminated hyperbranched oligomer shale inhibitor." Journal of Applied Polymer Science 136, no. 21 (February 8, 2019): 47573. http://dx.doi.org/10.1002/app.47573.

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Zhang, Rongjun, Yun Bai, Yan Sun, Weichao Du, Chunsheng Pu, Jie Zhang, and Gang Chen. "Preparation of Ammonium Oleic Acid Salts and Their Evaluation as Shale Swelling Inhibitors in Water-Based Drilling Fluid." Tenside Surfactants Detergents 58, no. 4 (July 1, 2021): 311–16. http://dx.doi.org/10.1515/tsd-2019-2238.

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Abstract In this paper, ammonium oleic acid salts (AOS) were prepared from oleic acid and amines and investigated as low molecular weight shale swelling inhibitors. First, the inhibitory effect of AOS was investigated using the linear expansion test of bentonite. The results show that the inhibitor prepared from oleic acid and tetraethylene pentamine with a molar ratio of 1:2 (AOS-8) has an excellent inhibitory effect on the hydration expansion of bentonite. The inhibitory effect of AOS-8 on bentonite was further investigated in subsequent work steps using various methods, including the linear swelling test of clay and particle distribution measurement. The results show that AOS-8 has superior performance in inhibiting hydration swelling and dispersion of bentonite. With 0.5% AOS-8, the swelling rate was reduced to 37.7%, and the particle size of bentonite in water could be controlled with AOS-8. Finally, the inhibition mechanism of AOS-8 was determined in detail by scanning electron microscopy (SEM) and thermogravimetric analysis (TGA). In water-based drilling fluid, AOS-8 is compatible with conventional additives. It can also significantly improve the lubricating capacity of the mud cake after ageing at 120°C.

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Liu, Jingping, Zhiwen Dai, Congjun Li, Kaihe Lv, Xianbin Huang, Jinsheng Sun, and Bing Wei. "Inhibition of the Hydration Expansion of Sichuan Gas Shale by Adsorption of Compounded Surfactants." Energy & Fuels 33, no. 7 (June 9, 2019): 6020–26. http://dx.doi.org/10.1021/acs.energyfuels.9b00637.

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Davarpanah, Afshin. "Integrated feasibility analysis of shale inhibition property by utilization of pore pressure transmission equipment." Petroleum Research 3, no. 2 (June 2018): 152–58. http://dx.doi.org/10.1016/j.ptlrs.2018.03.006.

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Saleh, Tawfik A., Azeem Rana, and Mohammed K. Arfaj. "Graphene grafted with polyethyleneimine for enhanced shale inhibition in the water-based drilling fluid." Environmental Nanotechnology, Monitoring & Management 14 (December 2020): 100348. http://dx.doi.org/10.1016/j.enmm.2020.100348.

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Sun, Pinghe, Junyi Zhu, Binkui Zhao, Xinxin Zhang, Han Cao, Mingjin Tian, Meng Han, and Weisheng Liu. "Study on the Mechanism of Ionic Stabilizers on Shale Gas Reservoir Mechanics in Northwestern Hunan." Energies 12, no. 12 (June 25, 2019): 2453. http://dx.doi.org/10.3390/en12122453.

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The shale of the lower Cambrian Niutitang formation in northwestern Hunan is an ideal reservoir for shale gas. There is a close connection between borehole stability and drilling fluid in shale gas drilling. Ionic stabilizer is a new type of stratum consolidation agent that inhibits the hydration expansion of clay minerals and improves mechanical strength of the borehole. The traditional idea of pore wall protection is to use drilling fluid additives to prevent shale from interacting with water. However, ionic stabilizer can change the hydrophilic of clay minerals in shale, making the particles become hydrophobic and dense, therefore, the formation stability can be enhanced simultaneously. The material used in this paper is different from the normal ionic stabilizer, some chemical bonds that have been changed in the new material called enhanced normality ionic (ENI) stabilizer. This paper utilized the shale samples those obtained from Niutitang formation to study the connection between ENI and the mechanical properties of shale. Mechanical tests and microscopic pore tests were performed on different samples which were soaked in water and the ENI with different concentrations. It has been found through tests that ENI can inhibit the development of shale pores, and as the concentration increases, the inhibition increases. In addition, as the ENI concentration increases, the uniaxial compressive strength and Young’s modulus of the shale increase, and the ratio of stability coefficients decreases. It can be concluded that the ENI can improve the mechanical strength of carbon shale, and prevent the development of rock damage. Moreover, it can improve the ability of rock to resist damage, and enhance borehole stability initiatively.

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39

Palumbo, Gaetano, Kamila Kollbek, Roma Wirecka, Andrzej Bernasik, and Marcin Górny. "Effect of CO2 Partial Pressure on the Corrosion Inhibition of N80 Carbon Steel by Gum Arabic in a CO2-Water Saline Environment for Shale Oil and Gas Industry." Materials 13, no. 19 (September 23, 2020): 4245. http://dx.doi.org/10.3390/ma13194245.

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The effect of CO2 partial pressure on the corrosion inhibition efficiency of gum arabic (GA) on the N80 carbon steel pipeline in a CO2-water saline environment was studied by using gravimetric and electrochemical measurements at different CO2 partial pressures (e.g., PCO2 = 1, 20 and 40 bar) and temperatures (e.g., 25 and 60 °C). The results showed that the inhibitor efficiency increased with an increase in inhibitor concentration and CO2 partial pressure. The corrosion inhibition efficiency was found to be 84.53% and 75.41% after 24 and 168 h of immersion at PCO2 = 40 bar, respectively. The surface was further evaluated by scanning electron microscopy (SEM), energy dispersive spectroscopy (EDS), grazing incidence X-ray diffraction (GIXRD), and X-ray photoelectron spectroscopy (XPS) measurements. The SEM-EDS and GIXRD measurements reveal that the surface of the metal was found to be strongly affected by the presence of the inhibitor and CO2 partial pressure. In the presence of GA, the protective layer on the metal surface becomes more compact with increasing the CO2 partial pressure. The XPS measurements provided direct evidence of the adsorption of GA molecules on the carbon steel surface and corroborated the gravimetric results.

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Lv, Kaihe, Xianbin Huang, He Li, Jinsheng Sun, Weichao Du, and Mao Li. "Modified Biosurfactant Cationic Alkyl Polyglycoside as an Effective Additive for Inhibition of Highly Reactive Shale." Energy & Fuels 34, no. 2 (January 23, 2020): 1680–87. http://dx.doi.org/10.1021/acs.energyfuels.9b04131.

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41

Das, B., B. Borah, and S. Bhattacharyya. "COMPARATIVE ANALYSIS OF CARBOXYMETHYL CELLULOSE AND PARTIALLY HYDROLYZED POLYACRYLAMIDE – LOW-SOLID NONDISPERSED DRILLING MUD WITH RESPECT TO PROPER-TY ENHANCEMENT AND SHALE INHIBITION." Resource-Efficient Technologies, no. 2 (August 26, 2020): 24–33. http://dx.doi.org/10.18799/24056537/2020/2/262.

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During drilling, different problems are encountered that can interfere with smooth drilling processes, including the accumulation of cuttings, reduced penetration rates, pipe sticking, loss of wellbore stability, and loss of circulation. These problems are generally encountered with conventional drilling mud, such as the bentonite–barite mud system. Formation damage is the most common problem encountered in bentonite mud systems with high solid content. In this work, we aimed to formulate two low-solid nondispersed (LSND) muds: carboxymethyl cellulose (CMC)–LSND mud and partially hydrolyzed polyacrylamide (PHPA)–LSND mud. A comparative analysis was performed to evaluate their property enhancements. LSND muds aid in maintaining hole stability and proper cutting removal. The results of this work show that the addition of both CMC and PHPA helps to improve drilling fluid properties; however, the PHPA–LSND mud was found to be superior. Shale swelling is a major concern in the petroleum industry, as it causes various other problems, such as pipe sticking, low penetration rates, and bit wear. The effect of these two LSND polymer muds in inhibiting shale swelling was analyzed using shale collected from the Champhai district of Mizoram, India.

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Wang, Wei, Amy T. Kan, Fangfu Zhang, Chao Yan, and Mason B. Tomson. "Measurement and Prediction of Thermal Degradation of Scale Inhibitors." SPE Journal 19, no. 06 (May 16, 2014): 1169–76. http://dx.doi.org/10.2118/164047-pa.

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Summary As the oil and gas industry is making firm strides in deepwater and shale exploration and development, possible thermal degradation of scale-inhibitor molecules poses a great challenge for scaling control and flow assurance for high-temperature reservoirs. Although extensive research has been conducted to test thermal stability of scale inhibitors, little work has been devoted to study the thermodynamics/kinetics of thermal degradation of scale inhibitors. In this work, a novel and efficient testing approach based on inhibition kinetics has been developed and successfully applied to determine the fraction of the active inhibitor molecules in preheated samples of scale inhibitors with various generic chemistries. Moreover, for the first time, we have modeled the kinetics of inhibitor thermal degradation on the basis of the integrated first-order rate equation and Arrhenius equation, with good agreements between the model predictions and experimental data. The preheated scale inhibitors have been analyzed by nuclear-magnetic-resonance (NMR) spectroscopy for organic-compound characterization. Our results and predictions based on inhibition testing assay are consistent with the 31P/1H NMR analyses. This work has enabled an in-depth understanding of the time and temperature dependence of thermal degradation of scale inhibitors, and facilitates the rational selection and deployment of scale inhibitors for high-temperature oil and gas production.

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Zhong, H. Y., W. A. Huang, Z. S. Qiu, J. Cao, B. Q. Xie, F. W. Wang, and W. Zheng. "Inhibition Comparison Between Polyether Diamine and Formate Salts as Shale Inhibitor in Water-based Drilling Fluid." Energy Sources, Part A: Recovery, Utilization, and Environmental Effects 37, no. 18 (September 14, 2015): 1971–78. http://dx.doi.org/10.1080/15567036.2011.654315.

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44

Shu, Xiaobo, Liping Wan, and Mubai Duan. "Persistent inhibition performance of amine polymers to inhibit clay swelling." Journal of Polymer Engineering 38, no. 4 (April 25, 2018): 323–31. http://dx.doi.org/10.1515/polyeng-2016-0428.

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AbstractClay hydration and swelling can cause shale instability in the drilling of oil and gas wells. The persistent inhibition performance of polyether amine (PEA) and poly(vinyl alcohol-g-dimethyl aminopropyl methacrylamide) (PVA-g-DMAPMA) as amine clay inhibitors has been investigated through hot rolling dispersion test, bulk hardness test, and bentonite inhibition test. The micro-mechanism has also been explained by Fourier transform infrared spectroscopy (FTIR), thermogravimetric analysis (TGA), scanning electron microscope (SEM), and X-ray diffraction (XRD) analyses. Through the interaction of PEA and PVA-g-DMAPMA, the PEA can enter into clay platelets to exclude water molecules from entering and hydrating the clay, and the PVA-g-DMAPMA can affect the surface of clay minerals to prevent further intrusion of water molecules. Due to the effect of multiple cationic sites, both PEA and PVA-g-DMAPMA can maintain persistent clay inhibition and are less susceptible to reversing the adsorption.

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Wu, Jun Kang, Hou Ying Xu, Yu Ning Xie, and Xiao Yu Zhou. "A Research and Application of Strong Inhibition Drilling Fluid." Applied Mechanics and Materials 675-677 (October 2014): 1481–84. http://dx.doi.org/10.4028/www.scientific.net/amm.675-677.1481.

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Thick coal seam BK block the distribution appears below 2500 meters long, loose and mixed carbonaceous mudstone. Release a new borehole pressure after the drill will cause collapse block falling, finally form an approximate elliptical hole, such as malignant accidents caused by its drill, bit freezing trip even well abandonment. Through three times of immersion test evaluation of the anti collapse ability of NH-1 core, NH-1 drilling fluid system has been optimized. Results show that, the drilling fluid has strong inhibition and anti pollution. The plastic viscosity is 24 mPa·s, the shear stress of 11Pa and the permeability recovery value reached (81.9-89.6)%. The success of the test card 21 Ping 1 well shows that the system of NH-1 drilling fluid has strong inhibition can effectively solve the Jurassic coal and carbonaceous shale collapse, the current high lubricating performance, can effectively improve the drilling speed, at the same time, its performance for reservoir protection, control the rheological properties of drilling fluid, improve the anti pollution and reduce the occurrence of downhole complicated conditions. Therefore, it can be in the sloughing formation for drilling operation reference for future.

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Barati, Pezhman, Khalil Shahbazi, Mosayyeb Kamari, and Amir Aghajafari. "Shale hydration inhibition characteristics and mechanism of a new amine-based additive in water-based drilling fluids." Petroleum 3, no. 4 (December 2017): 476–82. http://dx.doi.org/10.1016/j.petlm.2017.05.003.

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47

Zhong, H. Y., Z. S. Qiu, W. A. Huang, J. Cao, F. W. Wang, and B. Q. Xie. "Inhibition Comparison between Polyether Diamine and Quaternary Ammonium Salt as Shale Inhibitor in Water-based Drilling Fluid." Energy Sources, Part A: Recovery, Utilization, and Environmental Effects 35, no. 3 (February 2013): 218–25. http://dx.doi.org/10.1080/15567036.2011.606871.

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48

Oseh, Jeffrey O., M. N. A. M. Norddin, Hakim N. Muhamad, Issham Ismail, Afeez O. Gbadamosi, Augustine Agi, Abdul R. Ismail, and Shafeeq O. Blkoor. "Influence of (3–Aminopropyl) triethoxysilane on entrapped polypropylene at nanosilica composite for shale swelling and hydration inhibition." Journal of Petroleum Science and Engineering 194 (November 2020): 107560. http://dx.doi.org/10.1016/j.petrol.2020.107560.

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Lv, Kai He, Xue Dong Wu, Tao Shi, Kuan Long Ren, and Yu Xia Liu. "An High-Performance Water-Based Drilling Fluid and its Application." Advanced Materials Research 476-478 (February 2012): 2304–10. http://dx.doi.org/10.4028/www.scientific.net/amr.476-478.2304.

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An high-performance water-based drilling fluid is a hot subject of research both at home and abroad in recent years. In this paper, the inhibition property and the influence of amino polyols AP-1 and aluminum polymer DLP-1 on drilling fluid properties were evaluated, on this basis, through the formula optimization, the high-performance water based drilling fluid was developed and and field applied. Both laboratory study and field application showed that aluminum polymer can reduce viscosity and filtration rate, and can effectively inhibit the hydration expansion of clay. Amino polyols had a little effect on the viscosity, gel strength and filtration of drilling fluid, but it had a good shale inhibition. This drilling fluid has good properties in rheology, filtration, inhibition and anti-contamination, with a satisfactory overall performance, which is helpful in solving wellbore instability that are due to unenven hydration or well developed micro fractures.

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Du, Weichao, Michal Slaný, Xiangyun Wang, Gang Chen, and Jie Zhang. "The Inhibition Property and Mechanism of a Novel Low Molecular Weight Zwitterionic Copolymer for Improving Wellbore Stability." Polymers 12, no. 3 (March 23, 2020): 708. http://dx.doi.org/10.3390/polym12030708.

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In this work, a novel low molecular weight zwitterionic copolymer for improving wellbore stability, which is expected to be an alternative to the current shale inhibitors, was obtained by copolymerization of tris hydroxyethyl allyl ammonium bromide (THAAB), 2-acrylamido-2- methyl propane sulfonic acid (AMPS) and acrylamide (AM), initiated by a redox initiation system in an aqueous solution. The copolymer, denoted as SX-1, was characterized by FT-IR, TGA-DSC, and GPC. Results demonstrated that the molecular weight of SX-1 was approximately 13,683 g/mol and it displayed temperature resistance up to 225 °C. Regarding the inhibition performance, evaluation experiments showed the hot rolling recovery of a Longmaxi shale sample in 2.0 wt % SX-1 solutions was up to 90.31% after hot rolling for 16 h at 120 °C. The Linear swelling height of Na-MMT artificial core in 2.0 wt % SX-1 solution was just 4.74 mm after 16 h. Methods including particle size analysis, FTIR, XRD, and SEM were utilized to study the inhibition mechanism of SX-1; results demonstrated that SX-1 had entered into the inner layer of sodium montmorillonite (Na-MMT) and adsorbed on the inner surface, and the micro-structure of Na-MMT was successfully changed by SX-1. The particle size of Na-MMT in distilled water was 8.05 μm, and it was observed that its size had increased to 603 μm after the addition of 2.0 wt % of SX-1. Its superior properties make this novel low molecular weight copolymer promising for ensuring wellbore stability, particularly for high temperature wells.

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