Fracture propagation laws in staged hydraulic fracturing and their effects on fracture conductivities

Bao, Jin; Liu, He; Zhang, Guangming; Jin, Juan; Wan, Cheng; Liu, Jiandong

doi:10.1016/s1876-3804(17)30035-6

Cited by 17 publications

(3 citation statements)

References 21 publications

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“…In view of this mathematical model, numerical simulation research on multi-cluster fracture initiation has been carried out by many domestic and foreign scholars. Sepehri et al [11][12][13] studied the effect of interference between clusters on fracture pattern by considering fluid loss and fluid distribution among clusters and optimized the cluster spacing in multi fracture expansion. Li et al [14,15] found that the less stress difference causes greater fracture deflection when considering the effect of stress difference on fracture expansion.…”

Section: Nomenclature Umentioning

confidence: 99%

Factors Influencing Fracture Propagation in Collaborative Fracturing of Multiple Horizontal Wells

Gong,

Chen,

Cheng

et al. 2024

ENERGY

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Horizontal well-stimulation is the key to unconventional resource exploration and development. The development mode of the well plant helps increase the stimulated reservoir volume. Nevertheless, fracture interference between wells reduces the fracturing effect. Here, a 2D hydro-mechanical coupling model describing hydraulic fracture (HF) propagation is established with the extended finite element method, and the effects of several factors on HF propagation during multiple wells fracturing are analyzed. The results show that with an increase in elastic modulus, horizontal principal stress difference and injection fluid displacement, the total fracture area and the reservoir stimulation efficiency are both improved in all three fracturing technologies. After a comparison of the three technologies, the method of improved zipper fracturing is proposed, which avoids mutual interference between HFs, and the reservoir stimulation effect is improved significantly. The study provides guidance for optimizing the fracturing technology of multiple horizontal wells.

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Section: Nomenclature Umentioning

confidence: 99%

Factors Influencing Fracture Propagation in Collaborative Fracturing of Multiple Horizontal Wells

Gong,

Chen,

Cheng

et al. 2024

ENERGY

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“…Hydraulic fracturing, also commonly referred to as “fracking”, is a famously employed well stimulation technique that involves fracturing shale-rock formations by injecting a pressurized fluid. , In this process, a synthesized fracking fluid is pumped into the wellbore at high pressures to propagate cracks (fractures) in the deep rock formations creating interconnected fracture channel pathways as passages for the entrapped hydrocarbon to flow out into the production tubing. − The fracking fluid comprises various components such as water, proppant particles, polymers, chemicals, etc. , When the hydraulic pressure is removed from the well, the injected proppant grains’ main purpose is to hold the fractures open for hydrocarbon production. − …”

Section: Introductionmentioning

confidence: 99%

A Multiwalled Carbon Nanotube-Based Polyurethane Nanocomposite-Coated Sand/Proppant for Improved Mechanical Strength and Flowback Control in Hydraulic Fracturing Applications

et al. 2021

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A novel resin-based nanocomposite-coated sand proppant is introduced to address the issue of proppant flowback in post-fracturing fluid flowback treatments and hydrocarbon production. Self-aggregation in the water environment is the most attractive aspect of these developed proppants. In this work, sand was sieve-coated with 0.1% multiwalled carbon nanotubes (MWCNTs) followed by optimized thin and uniform resin (polyurethane) spray coating in the concentration range of 2 to 10%. Quantitative and qualitative evaluations have been carried out to assess the self-aggregation capabilities of the proposed sand proppants where no flowback was witnessed at 4% polyurethane coating containing 0.1% MWCNTs. This applied resin incorporating MWCNT coating was characterized by field emission scanning electron microscopy, and energy-dispersive X-ray spectroscopy depicted the dispersed presence of MWCNTs into polyurethane resin corroborated by the presence of 38% elemental carbon on the sand substrate. Proppant crushing resistance tests were conducted, including proppant pack stress−strain response, compaction, and fines production. It was found that the proposed sand proppant decreased the proppant pack compaction by ∼25% compared to commonly used silica sand with the ability to withstand high closure stress as high as 55 MPa with less than 10 wt % fines production. The surface wettability was determined by the sessile drop method. The application of resin incorporating MWCNT coating layers changed the sand proppant wetting behavior to oil-wet with a contact angle of ∼124°. Thermogravimetric analyses revealed a significant increment in thermal stability, which reached up to 280 °C due to the addition of MWCNTs as reinforcing nanofillers.

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“…Hydraulic fracturing (HF) is commonly implemented as a production improvement technique in the oil and gas industries (Cipolla, 2009;Haddad and Sepehrnoori, 2015;Li et al, 2015;Sanematsu et al, 2015;Bao et al, 2017;Liu et al, 2018). To date, the application of HF has been well justified.…”

Section: Introductionmentioning

confidence: 99%

Application of nanofluids for treating fines migration during hydraulic fracturing: Experimental study and mechanistic understanding

Moghadasi

Rostami

Hemmati-Sarapardeh

2019

Adv. Geo-Energy Res.

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Hydraulic fracturing has emerged as one of the best and most economical methods for enhancing oil recovery from low permeability reservoirs. However, its performance will be negatively affected by fines migration due to the hydraulic fracturing process. In the present study, it has been tried to experimentally investigate the efficiency of synthesized nanosilica particles in reducing fines migration. To this end, two sets of static and dynamic experiments, namely glass bead funnel test and core displacement analysis, were implemented, respectively. In the static test, increasing the soaking time and addition of nanosilica led to the clearer effluent fluid, resulting in fewer concentrations of clay particles in solution. When the mixture of nanosilica and glass beads was available in the solution, a higher differential pressure was obtained during a dynamic condition in comparison to only glass beads, which means the lower permeability of the porous media. Moreover, Derjaguin-Landau-Verwey-Overbeek theory was applied to demonstrate the clay particles absorption on the sand proppants surfaces. Consequently, it was observed that the use of nanosilica particles mixed with sand proppant can effectively reduce fines migration; thereby, it can enhance the hydraulic performance of the fracturing operation.

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Fracture propagation laws in staged hydraulic fracturing and their effects on fracture conductivities

Cited by 17 publications

References 21 publications

Factors Influencing Fracture Propagation in Collaborative Fracturing of Multiple Horizontal Wells

Factors Influencing Fracture Propagation in Collaborative Fracturing of Multiple Horizontal Wells

A Multiwalled Carbon Nanotube-Based Polyurethane Nanocomposite-Coated Sand/Proppant for Improved Mechanical Strength and Flowback Control in Hydraulic Fracturing Applications

Application of nanofluids for treating fines migration during hydraulic fracturing: Experimental study and mechanistic understanding

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