A Novel Environment-Friendly Natural Extract for Inhibiting Shale Hydration

Zhang, Fan; Sun, Jinsheng; Chang, Xiaofeng; Xu, Zhe; Zhang, Xianfa; Huang, Xianbin; Liu, Jingping; Lv, Kaihe

doi:10.1021/acs.energyfuels.9b01166

Cited by 28 publications

(20 citation statements)

References 42 publications

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“…Figure 1 shows the FT-IR of PNBAM. As shown in Figure 1 , the stretching vibrational peaks of the N–H, C=O, and C-N bonds present in the amide group occur at 3562, 1683, and 1172 cm −1 , respectively [ 34 , 35 , 36 ]. The stretching vibration peaks of –CH 3 and –CH 2 in the isopropyl group appear at 3080 and 2980 cm −1 , respectively, and the bending vibration peak appears at 1458 cm −1 [ 36 , 37 ].…”

Section: Resultsmentioning

confidence: 99%

A Temperature-Sensitive Polymeric Rheology Modifier Used in Water-Based Drilling Fluid for Deepwater Drilling

Wang

Sun

Zhang

et al. 2022

Gels

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Rheology modifiers are essential for the flat rheology of water-based drilling fluids in deepwater. The low temperature thickening of deepwater water-based drilling fluids results in dramatic rheological changes in the 20–30 °C range. To address such problems, NIPAM with a self-polymerized product LCST of 32–35 °C was selected as the main body for synthesis. While introducing the hydrophilic monomer AM to enhance the thickening properties, the hydrophobic monomer BA was selected to reduce the LCST of the product. In this paper, a temperature-sensitive polymeric rheology modifier (PNBAM) was synthesized by emulsion polymerization using N-isopropyl acrylamide, acrylamide, and butyl acrylate as monomers. The PNBAM was characterized using infrared spectroscopy (FT-IR), thermogravimetric analysis (TGA), and nuclear magnetic resonance hydrogen spectroscopy (NMR). The rheological properties, temperature resistance, and salt resistance of PNBAM in the base fluid (BF) were tested. The performance of PNBAM in the drilling fluid system was also evaluated, and a water-based drilling fluid system of flat rheology for deepwater was formulated. The rheological modification mechanism of PNBAM was analyzed by turbidity analysis, particle size analysis, and zeta analysis. Experimental results show that PNBAM has good rheological properties. PNBAM is temperature resistant to 150 °C, salt-resistant to 30 wt%, and calcium resistant to 1.0 wt%. PNBAM also has good flat rheology characteristics in drilling fluid systems: AV4°C:AV25°C = 1.27, PV4°C:PV25°C = 1.19. Mechanistic analysis showed that the LCST (Lower Critical Solution Temperature) of 0.2 wt% PNBAM in an aqueous solution was 31 °C. Through changes in hydrogen bonding forces with water, PNBAM can regulate its hydrophilic and hydrophobic properties before and after LCST, which thus assists BF to achieve a flat rheological effect. In summary, the temperature-sensitive effect of PNBAM has the property of enhancing with increasing temperature. While the tackifying effect of conventional rheology modifiers diminishes with increasing temperature, the temperature-sensitive effect of PNBAM gives it an enhanced thickening effect with increasing temperature, making it a more novel rheology modifier compared to conventional treatment additives. After LCST, compared to conventional rheology modifiers (XC), PNBAM has a more pronounced thermo-thickening effect, improving the main rheological parameters of BF by more than 100% or even up to 200% (XC less than 50%). This contributes to the flat rheology of drilling fluids. PNBAM has good application prospects and serves as a good reference for the development of other rheology modifiers.

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Section: Resultsmentioning

confidence: 99%

A Temperature-Sensitive Polymeric Rheology Modifier Used in Water-Based Drilling Fluid for Deepwater Drilling

Wang

Sun

Zhang

et al. 2022

Gels

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“…Guancheng et al evaluated the shale inhibition performance of the cationic polymer polyethyleneimine (PEI) with different molecular weights and reported that PEI has better performance than other inhibitors widely applied in the oil field. Besides, other shale inhibitors such as biomaterials − and nanoparticles also attracted intensive attention in the research field. However, for highly reactive shale formation, the available shale inhibitors could not meet the requirements of on-site engineering.…”

Section: Introductionmentioning

confidence: 99%

Modified Biosurfactant Cationic Alkyl Polyglycoside as an Effective Additive for Inhibition of Highly Reactive Shale

Huang

et al. 2020

Energy Fuels

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The wellbore instability caused by shale hydration in highly reactive shale formation is a troublesome problem during the oil and gas drilling process. In this study, cationic alkyl polyglycoside (CAPG) was synthesized by the etherification of C4 APG and applied to inhibit shale hydration. Using a highly reactive shale sample, the inhibiting performance of CAPG was studied by the mud ball immersing test, linear swelling test, shale recovery test, and bentonite inhibition test. The inhibiting mechanism was studied by experiments of surface tension, contact angle, particle size, X-ray diffraction, scanning electron microscopy (SEM), and Fourier transform infrared spectroscopy. Evaluation of experimental results proved that CAPG had the best inhibition performance for highly reactive shale among the inhibitors studied in this work. Especially, CAPG has a substantially higher shale recovery ratio of 87.08%, while the shale recovery ratio of water is merely 5.41%. According to the mechanism analysis, the excellent inhibition performances of CAPG could be explained in three aspects. First, CAPG could reduce surface tension, reducing water infiltration into shale caused by capillary pressure. Second, CAPG could enter interlayer spaces of bentonite. The multipoint adsorption of CAPG on the clay surface caused by electrostatic attraction and hydrogen bonding could isolate water and neutralize negative charges on the clay surface, which is beneficial in reducing both surface hydration and osmotic hydration of clay. Third, CAPG could substantially decrease porosity of the shale surface according to SEM, reducing water invasion, which is probably because the CAPG aggregates (particle size is 248.5 nm for 1 wt % solution) plug shale pores. This paper provided an effective method to inhibit highly reactive shale.

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“…33,34 The search for monomeric organic compounds from natural extracts, with shale inhibition potentials similar to or better than the conventional clay stabilizers, like KCl, is on the rise. 35 These compounds should be biodegradable, nontoxic, less expensive, and easily accessible. 36 A present research goal is to develop effective ultra-lowmolecular-weight stabilizers capable of satisfying the environmental regulation rules for aquatic ecosystems.…”

Section: Introductionmentioning

confidence: 99%

“…Again, the move toward compounds that leave little or no environmental footprints is increasing due to the stringent rules from environmental agencies. , The search for monomeric organic compounds from natural extracts, with shale inhibition potentials similar to or better than the conventional clay stabilizers, like KCl, is on the rise . These compounds should be biodegradable, nontoxic, less expensive, and easily accessible .…”

Section: Introductionmentioning

confidence: 99%

“…These compounds should be biodegradable, nontoxic, less expensive, and easily accessible . A present research goal is to develop effective ultra-low-molecular-weight stabilizers capable of satisfying the environmental regulation rules for aquatic ecosystems. , Regarding the issues raised and the properties needed to ensure effective and efficient inhibition of clay swelling, such as hydrogen bond affinity, excellent cationic radius, hydrophilic, and hydrophobic qualities, the consideration of monomeric organic compounds such as natural amino acids, for stabilizing swelling clays is worthwhile. , …”

Section: Introductionmentioning

confidence: 99%

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Inhibition Impact of Amino Acids on Swelling Clays: An Experimental and COSMO-RS Simulation Evaluation

et al. 2020

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The presence of swelling clays, namely, montmorillonite and illite-smectite mixed layer clays alike, significantly affects well stimulation processes, such as hydraulic fracturing. In this study, the inhibition potentials of three natural amino acids, namely, glycine, lysine monohydrochloride (lysine MHCl), and methionine, on the swelling properties of swelling clays were evaluated using laboratory and theoretical simulation techniques. Linear swelling tests, rheological analysis, zeta potential measurements, FTIR, and FESEM analyses were employed in this experimental work. COSMO-RS was then utilized theoretically to describe the physics by which the proposed amino acids inhibit the swelling of the clay minerals. The obtained results confirmed the clay stabilizing abilities of the studied amino acids. Glycine reduced the imbibition of water into the clay mineral twice better than KCl (a commonly used clay stabilizer), while methionine and lysine MHCl trailed behind glycine and KCl, respectively. Their clay swelling inhibition potentials were then compared to the base fluid: glycine (35%), KCl (18%), methionine (11%), and lysine MHCl (5%). The COSMO-RS simulation analysis confirmed that the inhibition performance of amino acids is mainly controlled by the following: (1) the activity coefficient (γ) between amino acids with water, (2) the hydrogen bonding energy (E HB ) between the amino acids and water, and (3) the side-chain length (p s ) or surface area of the amino acids. A multiple regression model was also developed using the predicted COSMO-RS properties (γ, E HB , and p s ). The model predictions strongly agreed with the experimental results with percentage errors of less than 0.2%. This study reveals that the unique inhibition potentials of amino acids are mostly dependent on their ability to form strong hydrogen bonds with water and clay minerals and their suitable activity coefficients with the base fluid. However, these unique inhibitive mechanisms vary for each natural amino acid due to their varying side chains. The consideration of amino acids as effective clay stabilizers for hydraulic fracturing activities is, therefore, a step in the right direction for replacing toxic fracturing fluid additives and path-charting the application of greener and cleaner processes for shale gas production.

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A Novel Environment-Friendly Natural Extract for Inhibiting Shale Hydration

Cited by 28 publications

References 42 publications

A Temperature-Sensitive Polymeric Rheology Modifier Used in Water-Based Drilling Fluid for Deepwater Drilling

A Temperature-Sensitive Polymeric Rheology Modifier Used in Water-Based Drilling Fluid for Deepwater Drilling

Modified Biosurfactant Cationic Alkyl Polyglycoside as an Effective Additive for Inhibition of Highly Reactive Shale

Inhibition Impact of Amino Acids on Swelling Clays: An Experimental and COSMO-RS Simulation Evaluation

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