Performance and field implementation of a new fracturing fluid consisting of hydrophobically associating polyacrylamide and anionic surfactant

Zhao, Zhongcong; Liu, Tongyi; Luo, Peng; Li, Yan; Liu, Jianxin; Cheng, Jiangmin; Yu, Yang

doi:10.1515/polyeng-2014-0344

Cited by 14 publications

(8 citation statements)

References 21 publications

(18 reference statements)

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“…Two or more identical or different thickener materials (biopolymer/surfactant, − synthetic polymer/surfactant, ,,, surfactant/surfactant, ,− etc.) are mixed according to a certain proportion.…”

Section: High-temperature-resistant Ves Fracturing Fluidsmentioning

confidence: 99%

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

Liu

et al. 2023

Energy Fuels

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A viscoelastic surfactant (VES) fluid is an important part of a water-based fracturing fluid. As oil and gas exploration expands into deep, high-temperature, low-permeability reservoirs, the conventional VES fracturing fluid has shown great limitations. The high-temperature-resistance mechanisms of the high-temperature-resistant VES fracturing fluids in publicly available literature were analyzed from five aspects: single-chain surfactant system, oligomeric surfactant system, counterion effect, blended surfactant system, and nano-enhanced VES system. The friction-reduction performance, sand-carrying performance, gel-breaking performance, and core-damage performance of these systems were summarized. The results show that oligomeric surfactants with a monounsaturated hydrophobic long chain (>C21) are most likely to be used for VES fracturing fluids in high-temperature reservoirs, but the loading of the surfactants is still relatively high (3–5 wt %). By reducing the repulsion among polar headgroups to effectively decrease the area of head groups, or/and penetrating into the nonpolar cores based on hydrophobic interaction to increase the average hydrophobic volume of hydrophobic tails, counterions affect the performance of VESs. The aromatic counterion salts are preferred choices for improving the temperature resistance, friction reduction, and suspended sand performance of VES fluids. The blended surfactant/synthetic polymer systems based on noncovalent interaction improve the temperature resistance of VES fluids and reduce the loading of the surfactants to a certain extent. Based on the “pseudo-cross-linking” of nanomaterials and wormlike micelles, a very small amount of nanomaterials can improve the temperature resistance of VES fluids and reduce the loading of the surfactants. The most essential and effective method to improve the temperature resistance of VES fluids for fracturing is the molecular structure design based on the packing parameter theory. However, the synthesis process or route still needs further optimization to reduce production costs. In addition, given the excellent performance of VES fluids enhanced by nanomaterials, further research should be conducted on the influence mechanism of nanomaterial type and geometric features on the performance of VESs, as well as the potential harmfulness of nanomaterials, to promote the field-scale application of nano-enhanced VES fluids.

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Section: High-temperature-resistant Ves Fracturing Fluidsmentioning

confidence: 99%

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

Liu

et al. 2023

Energy Fuels

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“…In the field application, the phenomenon of high apparent viscosity and weak sand suspension will also occur. In the past decade, hydrophobic associating polymers have been widely used (González et al 2011;Lara-Ceniceros et al 2007;Zhao et al 2016). Such systems do not follow the Cox-Merz rule and cannot be evaluated only by apparent viscosity (Seiffert 2016;Oppong and Bruyn 2010;Caram et al 2006;Vaccaro et al 2000).…”

Section: Introductionmentioning

confidence: 99%

Effect and mechanism of rheological properties and structure of a novel hydrophobically associating polymer on sand sedimentation rate

Zhao

Wang

Liu

et al. 2021

J Petrol Explor Prod Technol

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With hydrophobic associating polymer (BCG-1) and anionic surfactant sodium dodecyl benzene sulfonate (SDBS) solution as the object, this work studies the different polymer concentration and surfactant concentration on the influence law of fluid properties and examines the sand sedimentation rate and the correlation of fluid properties. After the liquid was tested by electron microscope and rheometer, it was found that the interaction between the surfactant and the polymer is with phases, which provided different angles for revealing the change rule of the deposition rate of sand. When the concentration of SDBS solution is in the second phase (0.05–0.2%), although the system property changes slightly and the microscopic morphology does not change greatly, the deposition rate of sand still decreases significantly. Relaxation time spectrometry explains that the reduction in the sedimentation rate of the sand is caused by the shift of the polymer chain motion mode, whereas the phase angle can clearly manifest this change, and the phase angle is highly correlated with the deposition rate of sand.

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“…Due to their good thickening ability, HAWSPs have been widely used in many aspects of oilfield operations [1]. especially in polymer flooding and hydraulic fracturing [2,3,4,5,6,7]. For example, HAWSPs are employed as one type of popular thickeners which can effectively carry sand without adding any crosslinking agents for fracturing application [4,5,6].…”

Section: Introductionmentioning

confidence: 99%

“…especially in polymer flooding and hydraulic fracturing [2,3,4,5,6,7]. For example, HAWSPs are employed as one type of popular thickeners which can effectively carry sand without adding any crosslinking agents for fracturing application [4,5,6]. In addition, the polymers themselves are completely soluble; hence, after gel breaking, formation damage caused by gel residue is very low (permeability reduced by less than 10%) [6].…”

Section: Introductionmentioning

confidence: 99%

Improving the Thermal Stability of Hydrophobic Associative Polymer Aqueous Solution Using a “Triple-Protection” Strategy

et al. 2019

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Because of their high viscoelasticity, Hydrophobic Associative Water-Soluble Polymers (HAWSPs) have been widely used in many industrial fields, especially in oilfield flooding and fracturing. However, one major problem which limits the wide applications of HAWSPs is their weak resistance to high temperatures. Once the temperature increases over 100 °C, the viscosity of the fracturing fluid decreases rapidly, because high temperatures reduce fluid viscosity by oxidizing the polyacrylamide chains and weakening the association of hydrophobic groups. To improve the high temperature resistance of one HAWSP, a triple-protection strategy was developed. First, rigid N-vinyl-2-pyrrolidone moiety was introduced into the polymer chains. Second, an environmentally-friendly deoxidizer, carbohydrazide, was selected to prevent polymer oxidization by scavenging dissolved oxygen. Results showed that both the rigid groups and the deoxidizer improved the temperature resistance of the polymer and helped it maintain high viscosity under high temperature and shear rate. Using these two protection strategies, the resistant temperature of the polymer could reach 160 °C. However, the polymer network still got severely damaged at further elevated temperatures. Therefore, as the third protection strategy, the pre-added high temperature responsive crosslinking agent was applied to form new networks at elevated temperatures. The results have shown that the optimized polymer solution as a kind of fracturing fluid showed good temperature resistance up to 200 °C.

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Performance and field implementation of a new fracturing fluid consisting of hydrophobically associating polyacrylamide and anionic surfactant

Cited by 14 publications

References 21 publications

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

Review on High-Temperature-Resistant Viscoelastic Surfactant Fracturing Fluids: State-of-the-Art and Perspectives

Effect and mechanism of rheological properties and structure of a novel hydrophobically associating polymer on sand sedimentation rate

Improving the Thermal Stability of Hydrophobic Associative Polymer Aqueous Solution Using a “Triple-Protection” Strategy

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