Rheological Performance of High-Temperature-Resistant, Salt-Resistant Fracturing Fluid Gel Based on Organic-Zirconium-Crosslinked HPAM

Xin, Hui; Fang, Bo; Yu, Luyao; Lü, Yongjun; Xu, Ke; Li, Kejing

doi:10.3390/gels9020151

Cited by 7 publications

(8 citation statements)

References 51 publications

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“…The viscosity of the polymer solution was stabilized at 72.25 mPa·s after shearing for 4 h at 150 °C and a 170 s –1 shear rate. It is superior to the field construction standard, in which viscosity is greater than 50 mPa·s . This indicates that the HTS-SSP surface hydratable material has a good temperature and shear resistance.…”

Section: Resultsmentioning

confidence: 96%

“…In order to prevent the surface hydratable material from blocking the pores between the proppant, the breaker is added to the fracturing fluid to break the surface hydratable material. Linear PAM gels can be destroyed by oxidizing agents. − Ammonium persulfate is a widely used gel breaker in hydraulic fracturing, which can degrade or break the molecular chains of polymers . Ammonium persulfate at different concentrations was added to the HTS-SSP system of 10, 20, 30, and 40% sand ratio.…”

Section: Resultsmentioning

confidence: 99%

“…It is superior to the field construction standard, in which viscosity is greater than 50 mPa•s. 35 This indicates that the HTS-SSP surface hydratable material has a good temperature and shear resistance.…”

Section: Temperature and Shear Resistance Of Hydratable Materialsmentioning

confidence: 94%

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High-Temperature and Salt-Resistant Self-Suspending Proppant for Hydraulic Fracturing

Zhang,

Wang,

Deng

et al. 2024

Energy Fuels

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In recent years, new technologies involving self-suspending proppant (SSP), which improves proppant distribution, reduces the use of chemicals in fracturing fluids, and simplifies the fracturing construction process, have become a focus of hydraulic fracturing research. However, the available products have poor suspension stability, cannot withstand high temperature and salt environments, and are highly damaging to reservoirs. In this study, we presented a novel self-suspending (HTS-SSP) proppant with excellent suspension stability, temperature resistance, and salt resistance, prepared from quartz sand, silane coupling agent, and modified polyacrylamide to achieve these properties. Wettability tests, surface morphology analysis, and Fourier transform infrared spectroscopy analysis proved that 3-methacryloxypropyltrmethoxysilane (KH570) successfully modifies quartz sand, and the HTS-SSP was synthesized. In terms of the suspension performance, HTS-SSP exhibited exceptional suspension stability due to the incorporation of KH570. It remained suspended at 150 °C or 24 wt % brine and showed excellent temperature and salt resistance. The gel-breaking fluid of the surface polymer of HTS-SSP had low damage to the reservoir, much less than the guar gum fluid. The difference between the conductivity of the aggregate remaining after HTS-SSP gel-breaking and that of unmodified quartz sand was not significant. The synthesized HTS-SSP demonstrates outstanding comprehensive performance and is an ideal candidate for reservoir development under harsh temperature and salinity conditions.

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Section: Resultsmentioning

confidence: 96%

Section: Resultsmentioning

confidence: 99%

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High-Temperature and Salt-Resistant Self-Suspending Proppant for Hydraulic Fracturing

Zhang,

Wang,

Deng

et al. 2024

Energy Fuels

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“…Hydraulic fracturing is an effective technique for stimulating low-permeability and ultralow-permeability oil and gas reservoirs. − A large amount of fracturing fluid is pumped to the bottomhole under high pressure to form the induced fractures, and the proppant is carried and transported into the fractures. The proppant located in the fractures will prevent the fractures from fully closing after fracturing operation, , resulting in a channel with permeability several orders of magnitude higher than the permeability of the formation itself. − The viscosity and elastic properties of the fracturing fluid are crucial for creating the designed fracture geometry and controlling the suspension efficiency of proppants. − Therefore, a reasonable selection of fracturing fluid is very important in hydraulic fracturing treatment.…”

Section: Introductionmentioning

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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“…Xin et al used organic Zr as crosslinker and studied the effects of temperature and strain on the crosslinking process of HPAM fracturing fluid through SAOS and LAOS rheological testing methods. It was founded that the crosslinker had the delayed crosslinking effect and higher temperature (70–90°C) and appropriate large shear ( γ < 50%) were conducive to crosslinking of the gel (Xin et al, 2023). Currently, there are few studies on delayed micellar formation of VES fracturing fluids.…”

Section: Introductionmentioning

confidence: 99%

Rheology and delayed micellar formation process of novel tetrameric cationic surfactant fracturing fluid

Fang

et al. 2023

J Surfact & Detergents

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To enrich the clean fracturing fluid system with high temperature resistance, a novel tetrameric cationic surfactant (TET) was developed and used as a thickener and mixed with different concentrations of sodium salicylate (NaSal) to obtain a new clean fracturing fluid. The flow curves, thixotropy, viscoelasticity, temperature resistance property, and proppant‐suspending capacity were further investigated. The rheological study showed that the Casson model could be used to accurately describe the flow curve of TET/NaSal micelle solutions and the addition of NaSal improved the thixotropy and viscoelasticity of surfactant solution. The optimal mass ratio of TET/NaSal solution was 5/1.5 wt%, and it had good proppant‐suspending capacity. What is more, the retained viscosity of TET/NaSal (5/1.5 wt%) solution was 52.27 mPa·s after shearing at 140°C and 100.0 s−1 for 65 min, which met industry requirements (viscosity > 20 mPa·s) of viscoelastic surfactant fracturing fluids. Moreover, the combination of 10 wt% TET aqueous solution with pH value of 8.51 and 2.6 wt% salicylic acid (HSal) suspension of the same mass significantly delayed micellar formation. The four‐parameter rheo‐kinetics model can be used to fit the viscosity curves of micellar formation, which provided the rheological basis for the study of delayed viscoelastic micellar formation.

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Rheological Performance of High-Temperature-Resistant, Salt-Resistant Fracturing Fluid Gel Based on Organic-Zirconium-Crosslinked HPAM

Cited by 7 publications

References 51 publications

High-Temperature and Salt-Resistant Self-Suspending Proppant for Hydraulic Fracturing

High-Temperature and Salt-Resistant Self-Suspending Proppant for Hydraulic Fracturing

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

Rheology and delayed micellar formation process of novel tetrameric cationic surfactant fracturing fluid

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