Experimental and theoretical investigation of a copolymer combined with surfactant for preventing scale formation in oil wells

Fernandes, Rafael da Silva; Beserra, Nurielly L.R.; Souza, Miguel Ângelo Fonseca de; Lima, Djalan F. de; Castro, Bruno Barbosa; Balaban, Rosângela de Carvalho

doi:10.1016/j.molliq.2020.114036

Cited by 16 publications

(3 citation statements)

References 54 publications

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“…In addition, the compressive strength of hydrogels with MBAm content and hydrophobe content (e.g., OMA 4 -PAAm/Alg/PDA hydrogel with MBAm 1.2% and MBAm 1.4% ) decreased sharply compared with that before immersion, indicating that unbalanced physical–chemical cross-linking has negative effects on the compressive strength of hydrogel adhesive materials. The double-network hydrogel can improve the sequestering effect with divalent cations in saline because of the cooperative coordination between the sulfate groups of SDS and carboxylate groups of alginates . However, excess SDS can drive the morphological transitions of surfactant micelles, which can induce excessive ionic complexation.…”

Section: Results and Discussionmentioning

confidence: 99%

“…The double-network hydrogel can improve the sequestering effect with divalent cations in saline because of the cooperative coordination between the sulfate groups of SDS and carboxylate groups of alginates. 43 However, excess SDS can drive the morphological transitions of surfactant micelles, 44 which can induce excessive ionic complexation. Unlike the transfer of high stress between adjacent alginate blocks in the process of unzipping, the ionic complexation formed between the sulfate group of SDS and cations cannot dissipate energy, consequently leading to a brittle hydrogel, accompanied by the decrease of strength.…”

Section: Mechanical Testmentioning

confidence: 99%

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High-Strength Hydrogel Adhesive Formed via Multiple Interactions for Persistent Adhesion under Saline

Min

Dai

et al. 2021

ACS Appl. Bio Mater.

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Hydrogel adhesives have been widely used in wet environments. Nonetheless, strong and stable persistent adhesion remains a challenge. Here, we report a facile yet powerful strategy to construct high-strength hydrogel adhesives for durable adhesion in a saline environment. Such a hydrogel consists of two polymer networks: a hydrophobic-associated polyacrylamide network of covalent and noncovalent cross-links and an alginate network cross-linked by divalent cations in saline. Meanwhile, polydopamine nanoparticles formed through in-situ self-polymerization are distributed evenly throughout the system to provide underwater adhesion. A low and controllable swelling rate and high compressive strength of hydrogels can be achieved via this multiple interaction strategy. Ultimately, this strategy contributes to the persistent underwater adhesion of hydrogels, and the decreasing rate of lap-shear adhesion strength of hydrogels is only 24.79 ± 8.01% after saline immersion for up to 21 days. Moreover, good cytocompatibility of hydrogels is helpful for their application in the biomedical field.

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Section: Results and Discussionmentioning

confidence: 99%

Section: Mechanical Testmentioning

confidence: 99%

High-Strength Hydrogel Adhesive Formed via Multiple Interactions for Persistent Adhesion under Saline

Min

Dai

et al. 2021

ACS Appl. Bio Mater.

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“…[11] Common green scale inhibitors include polyaspartic acid (PASP), polyepoxysuccinic acid (PESA) and their derivatives, all of which exhibit good inhibition performance in circulating water but are difficult to achieve excellent effect in the salt system due to the special salt-making environment. [12][13][14] Sulfonic acid can avoid the formation of calcium gel while reducing the amount of scale inhibitor because of its good hydrophilicity, [4,15,16] and thus can be used as scale inhibitor in a highly salty system. Zhang [17] synthesized a novel scale inhibitor using polyepoxysuccinic acid and sodium lignin sulfonate and measured its inhibition performance in brine by ion selective electrode, temperature and pressure simulation.…”

Section: Introductionmentioning

confidence: 99%

Synthesis, Performance and Mechanism of an Anionic Scale Inhibitor in a Salt System

Luo,

Sun,

Wang

et al. 2023

ChemistrySelect

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A novel non‐phosphorus and non‐nitrogen scale inhibitor IA‐HEMA was synthesized in the presence of only C, H and O using itaconic acid (IA) and 2‐hydroxyethyl methacrylate (HEMA) as the raw materials and hydrogen peroxide‐ascorbic acid (H2O2‐ASA) as the initiating system. The synthesis conditions were optimized with the response surface method (RSM). The results indicated that the material ratio had the largest effect on the scale inhibition rate, followed by initiator dosage, polymerization temperature and polymerization time successively. As demonstrated by the static scale inhibition experiment, the scale inhibition rate was 97.27 % when the IA‐HEMA concentration was 100 mg/L. The mechanism was explored by molecular dynamics (MD). The results indicated that IA‐HEMA was able to overcome its own distortion and adsorb on the crystal surface, and the scale inhibition performance was related to its chelating and lattice‐distortion ability, which effectively inhibited the formation and precipitation of scale. All these findings suggest that IA‐HEMA is a quite promising environmentally friendly scale inhibitor in the salt system.

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Prediction of barium sulfate precipitation in dynamic tube blocking tests and its inhibition for waterflooding application using response surface methodology

Khormali¹,

Ahmadi²

2023

J Petrol Explor Prod Technol

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Scale precipitation is one of the major problems in the petroleum industry during waterflooding. The possibility of salt formation and precipitation should be monitored and analyzed under dynamic conditions to improve production performance. Scale precipitation and its dependence on production parameters should be investigated before using scale inhibitors. In this study, the precipitation of barium sulfate salt was investigated through dynamic tube blocking tests at different injection rates and times. For this purpose, the pressure drop caused by salt deposition was evaluated at injection rates of 1, 2, 3, 4, and 5 mL/min. The software determined the worst conditions (temperature, pressure, and water mixing ratio) for barium sulfate precipitation. Moreover, during the experiments, the pressure drop caused by barium sulfate precipitation was measured without using scale inhibitors. The pressure drop data were evaluated by the response surface method and analysis of variance to develop a new model for predicting the pressure drop depending on the injection rate and time. The novelty of this study lies in the development of a new high-precision correlation to predict barium sulfate precipitation under dynamic conditions using the response surface methodology that evaluates the effect of injection rate and time on the possibility of salt precipitation. The accuracy and adequacy of the obtained model were confirmed by using R2 statistics (including R2-coefficient of determination, adjusted R2, and predicted R2), adequate precision, and diagnostic charts. The results showed that the proposed model could fully and accurately predict the pressure drop. Increasing the time and decreasing the injection rate caused an increase in pressure drop and precipitation of barium sulfate salt, which was related to the formation of more salt due to the contact of ions. In addition, in a short period of the injection process, the pressure drop due to salt deposition increased sharply, which confirms the need to use a suitable scale inhibitor to control salt deposition. Finally, the dynamic tube blocking tests were repeated in the presence of two well-known scale inhibitors, which prevented salt deposition in the tubes. At the same time, no pressure drop was observed in the presence of scale inhibitors at all injection rates during a long period of injection. The obtained results can be used for the evaluation of salt precipitation during oil production in the reservoirs, in which barium sulfate is precipitated during waterflooding. For this purpose, knowing the flow rate and injection time, it is possible to determine the amount of pressure drop caused by salt deposition.

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Experimental and theoretical investigation of a copolymer combined with surfactant for preventing scale formation in oil wells

Cited by 16 publications

References 54 publications

High-Strength Hydrogel Adhesive Formed via Multiple Interactions for Persistent Adhesion under Saline

High-Strength Hydrogel Adhesive Formed via Multiple Interactions for Persistent Adhesion under Saline

Synthesis, Performance and Mechanism of an Anionic Scale Inhibitor in a Salt System

Prediction of barium sulfate precipitation in dynamic tube blocking tests and its inhibition for waterflooding application using response surface methodology

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