A Mechanical Methodology of Improved Proppant Transport in Low-Viscosity Fluids: Application of a Fiber-Assisted Transport Technique in East Texas

2004 ◽  
Author(s):  
J.N. Engels ◽  
E. Martinez ◽  
C.N. Fredd ◽  
C.L. Boney ◽  
B.A. Holms
Keyword(s):  
East Texas ◽  
Proppant Transport ◽  
Low Viscosity ◽  
Transport Technique ◽  
Low Viscosity Fluids

scholarly journals Hydromechanical-Coupled Cohesive Interface Simulation of Complex Fracture Network Induced by Hydrofracturing with Low-Viscosity Supercritical CO2

Lithosphere ◽  
2021 ◽  
Vol 2021 (Special 1) ◽  
Author(s):  
Xin Cai ◽  
Wei Liu
Keyword(s):  
Hydraulic Fracturing ◽  
Supercritical Co2 ◽  
Fracture Propagation ◽  
Zone Model ◽  
Hydraulic Pressure ◽  
Small Aperture ◽  
Complex Fracture ◽  
Low Viscosity ◽  
Fracturing Fluids ◽  
Low Viscosity Fluids

Abstract Hydraulic fracturing experiments with low-viscosity fluids, such as supercritical CO2, demonstrate the formation of complex fracture networks spread throughout the rocks. To study the influence of viscosity of the fracturing fluids on hydraulic fracture propagation, a hydromechanical-coupled cohesive zone model is proposed for the simulation of mechanical response of rock grains boundary separation. This simulation methodology considers the synergistic effects of unsteady flow in fracture and rock grain deformation induced by hydraulic pressure. The simulation results indicate a tendency of complex fracture propagation with more branches as the viscosity of fracturing fluids decrease, which is in accord with experimental results. The low-viscosity fluid can flow into the microfractures with extremely small aperture and create more shear failed fracture. This study confirms the possibility of effective well stimulations by hydraulic fracturing with low-viscosity fluids.

scholarly journals Heterogeneous flow inside threads of low viscosity fluids leads to anomalous long filament lifetimes

2019 ◽  
Vol 9 (1) ◽  
Author(s):  
Steffen M. Recktenwald ◽  
Simon J. Haward ◽  
Amy Q. Shen ◽  
Norbert Willenbacher
Keyword(s):  
Heterogeneous Flow ◽  
Low Viscosity ◽  
Low Viscosity Fluids

scholarly journals Optimization of NMR spectroscopy of encapsulated proteins dissolved in low viscosity fluids

2011 ◽  
Vol 50 (4) ◽  
Author(s):  
Nathaniel V. Nucci ◽  
Bryan S. Marques ◽  
Sabrina Bédard ◽  
Jakob Dogan ◽  
John M. Gledhill ◽  
...  
Keyword(s):  
Nmr Spectroscopy ◽  
Low Viscosity ◽  
Encapsulated Proteins ◽  
Low Viscosity Fluids

Proppant Placement Using Alternate-Slug Fracturing

SPE Journal ◽  
2014 ◽  
Vol 19 (05) ◽  
pp. 974-985 ◽  
Author(s):  
Sahil Malhotra ◽  
Eric R. Lehman ◽  
Mukul M. Sharma
Keyword(s):  
High Viscosity ◽  
Mixing Zone ◽  
Proppant Transport ◽  
Fracture Length ◽  
The Past ◽  
Low Viscosity ◽  
Viscous Fingers ◽  
Wide Range ◽  
Design Calculations ◽  
Viscosity Fluid

Summary New fracturing techniques, such as hybrid fracturing (Sharma et al. 2004), reverse-hybrid fracturing (Liu et al. 2007), and channel (HiWAY) fracturing (Gillard et al. 2010), have been deployed over the past few years to effectively place proppant in fractures. The goal of these methods is to increase the conductivity in the proppant pack, providing highly conductive paths for hydrocarbons to flow from the reservoir to the wellbore. This paper presents an experimental study on proppant placement by use of a new method of fracturing, referred to as alternate-slug fracturing. The method involves an alternate injection of low-viscosity and high-viscosity fluids, with proppant carried by the low-viscosity fluid. Alternate-slug fracturing ensures a deeper placement of proppant through two primary mechanisms: (i) proppant transport in viscous fingers, formed by the low-viscosity fluid, and (ii) an increase in drag force in the polymer slug, leading to better entrainment and displacement of any proppant banks that may have formed. Both these effects lead to longer propped-fracture length and better vertical placement of proppant in the fracture. In addition, the method offers lower polymer costs, lower pumping horsepower, smaller fracture widths, better control of fluid leakoff, less risk of tip screenouts, and less gel damage compared with conventional gel fracture treatments. Experiments are conducted in simulated fractures (slot cells) with fluids of different viscosity, with proppant being carried by the low-viscosity fluid. It is shown that viscous fingers of low-viscosity fluid and viscous sweeps by the high-viscosity fluid lead to a deeper placement of proppant. Experiments are also conducted to demonstrate slickwater fracturing, hybrid fracturing, and reverse-hybrid fracturing. Comparison shows that alternate-slug fracturing leads to the deepest and most-uniform placement of proppant inside the fracture. Experiments are also conducted to study the mixing of fluids over a wide range of viscosity ratios. Data are presented to show that the finger velocities and mixing-zone velocities increase with viscosity ratio up to viscosity ratios of approximately 350. However, at higher viscosity ratios, the velocities plateau, signifying no further effect of viscosity contrast on the growth of fingers and mixing zone. The data are an integral part of design calculations for alternate-slug-fracturing treatments.

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