Study of Degradable Fibers With and Without Guar Gum As A Proppant Transport Agent Using A Large Scale Slot Equipment

Kim, Jung Yong; Zhou, Lijun; Morita, Nobuo

doi:10.2118/195808-ms

Cited by 6 publications

(2 citation statements)

References 20 publications

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“…On the contrary, larger-sized proppants form sand beds with good characteristics at the end close to the inlet; however, they do not favour proppant particles being transported to deeper fractures. [26][27][28] Another group of researchers studied proppant transport in different types of fracture (e.g., single, complex, inclined, and contracting fracture). [29][30][31][32][33][34][35] Some of these researchers, after studying the influence of fractures with a contracting width on proppant transport, concluded that irregular changes in fracture width will lead to changes in the flow pattern of sand-carrying fluid to generate a vortex, resulting in continuous damage to the fluidized layer by eddy particles, so that more stationary particles are resuspended, transported to deeper fractures, and the height of the sand bed is thus reduced.…”

Section: Introductionmentioning

confidence: 99%

Physical simulation study of proppant settling and migration within deep shale narrow fractures

Lin,

Zhang,

Yang

et al. 2023

Preprint

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Hydraulic fracturing is an important technology in shale gas reservoir development. Effective improvement of proppant sanding in the “long narrow fracture” in deep shale reservoirs is important. In this study, based on the simulation of long narrow fractures in deep shale reservoirs with a flat plate experimental setup, we conducted comparative experiments with various parameters (e.g., fracturing fluid viscosity, injection pump flow rate, proppant particle size, sand concentration, fracture width, and proppant type) to understand the settlement and migration pattern of the proppant particles in the long narrow fractures in deep shale reservoirs. The results showed that, compared to that in wide fractures, under the same conditions, the sand bed formed by proppant particles in the long narrow fracture in deep shale has a smaller front edge slope and lower height difference between the front and end of the sand bed, resulting in a more even and smooth overall sanding of proppant particles. In the long narrow fractures in deep shale, the percentage of the area of the sand bed at the outlet end to the area of the whole sand bed increases with fracturing fluid viscosity and the injection pump flow rate, while it is less influenced by the sand concentration. The micro-sized proppant particles also promote the placement of the sand bed at the outlet end and are more conducive to the overall uniform placement of the sand bed. The contracting width of the long narrow fracture in deep shale has no significant effect on the placement of the sand bed in the fracture in front of the contraction, but it impedes the proppant particle flow distribution in the fracture behind the contraction. The coverage area and equilibrium height of the sand bed after the contraction decreased, and the overall sanding was more even. However, the amount of settled proppant decreased, increasing the difficulty of effective fracture support in deep shale reservoir fractures. The results of this experimental research provide strong support to the reforming design of fracturing in deep shale reservoirs.

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Section: Introductionmentioning

confidence: 99%

Physical simulation study of proppant settling and migration within deep shale narrow fractures

Lin,

Zhang,

Yang

et al. 2023

Preprint

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“…The fracturing fluid transports the proppant during hydraulic fracturing to obtain the artificial fracture diversion channel . The high-quality hydraulic fracturing fluid aims to create sufficient fractures for oil and gas flow and control the proppant transportation . In practice, the water-based fracturing fluid is the most cost-effective choice.…”

Section: Introductionmentioning

confidence: 99%

Foam Stabilization Mechanism of a Novel Non-cross-linked Foam Fracturing Fluid

et al. 2021

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Traditional foam hydraulic fracturing fluids used guar crosslinking technology. However, major production problems, such as high friction and difficulty to accurately control the cross-linking time, have influenced the large-scale application of cross-linked guar foam fracturing fluids. In this study, we developed a novel non-cross-linked foam fracturing fluid using a series of polymers synthesized with acrylamide and hexadecyl trimethylallyl ammonium chloride as monomers and improved the stability of foam by forming structures in solution through association. The results showed that the hydrophobic groups were the key factors that affect the foam stability, and the hydrolysis degree had a significant effect on the elasticity of the polymer solution. The model association polymer with 0.75% hydrophobic group content and 56% hydrolytic degree was optimal. The stability of our proposed foam was comparable to that of the cross-linked guar gum foam. The adsorption of associating polymers on the gas and water interface resulted in a high-stability foam. Our study demonstrates a new avenue to develop high-stability foams to satisfy the current hydraulic fracturing scheme.

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Optimization Approach for Determination of the Dosage of Diversion Agents in Temporarily Plugging Fracturing of Shale Using 3D Printing Fractures

Wang

Che

Wang

et al. 2021

SPE Europec Featured at 82nd EAGE Conference and Exhibition

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Application of diversion agents in temporarily plugging fracturing of horizontal wells of shale has becoming more and more popular. Nevertheless, the studies on determining the diverter dosage are below adequacy. A novel approach based on laboratory experiments, logging data, rock mechanics tests and fracture simulation was proposed to optimizing the dosage of diversion agents. The optimization model is based on the classic Darcy Law. A pair of 3D-printed rock plates with rugged faces was combined to simulate the coarse hydraulic fractures with the width of 2.0 ~ 7.0 mm. The mixture of the diversion agents and slickwater was dynamically injected to the simulated fracture in Temco fracture conductivity system to mimic the practical treatment of temporarily plugging fracturing. The permeability of the temporary plugging zone in the 3D-printed fractures was measured in order to optimize the dosage of the selected diversion agents. The value of Pnet (also the value of ΔP in Darcy Formula) required for creation of new branched fractures was determined using the Warpinski-Teufel Failure Rules. The hydraulic fractures of target stages were simulated to obtain the widths and heights. The experimental results proved that the selected suite of the diversion agents can temporarily plug the 3D-printed fractures of 2.0 ~ 7.0 mm with blocking pressure up to 15 MPa. The measured permeability of the resulting plugging zones was 0.724 ~ 0.933 D (averaging 0.837 D). The value of Pnet required for creation of branched fractures in shale of WY area (main shale gas payzone of China) was determined as 0.4 ~ 15.6 MPa (averaging 7.9 MPa) which means the natural fractures and/or weak planes with approaching angle less than 70o could be opened to increase the SRV. The typical dosage of the diversion agents used for one stage of the horizontal wells was calculated as 232 ~ 310 kg. The optimization method was applied to the design job of temporarily plugging fracturing of two shale gas wells. The observed surface pressure rise after injection of diversion agents was 0.6 ~ 11.7 MPa (averaging 4.7 MPa) and the monitored microseismic events of the test stages were 37% more than those of the offset stages.

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Study of Degradable Fibers With and Without Guar Gum As A Proppant Transport Agent Using A Large Scale Slot Equipment

Cited by 6 publications

References 20 publications

Physical simulation study of proppant settling and migration within deep shale narrow fractures

Physical simulation study of proppant settling and migration within deep shale narrow fractures

Foam Stabilization Mechanism of a Novel Non-cross-linked Foam Fracturing Fluid

Optimization Approach for Determination of the Dosage of Diversion Agents in Temporarily Plugging Fracturing of Shale Using 3D Printing Fractures

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