Impact of proppant diagenesis on shale gas productivity

Patwardhan, Sanjay; Gunaji, Radhika G.; Kumar, G. Suresh

doi:10.1504/ijogct.2017.081096

Cited by 3 publications

(3 citation statements)

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“…A large volume of proppants is pumped into the formation to enhance transportation of shale gas from the formation to the wellbore in commercial quantities. − Such production requires the complex network of artificial fractures to have sufficient conductivity to sustain the whole period of production . Unfortunately, the techniques for transporting and placing proppants in the formation to hold the fractures exhibit formation damage near the fracture surface that affects fracture packing. − Many mechanisms impair the fracture conductivity during the process of fracturing. ,, These include proppant embedment, closure stress effect, , proppant crushing, , cyclic stress, fine migration, proppant pack diagenesis, , and the blockage caused by the gel residue in the proppant pack and gel filter cake at the fracture face. , …”

Section: Application Of Nanotechnology For Formation Damage Controlmentioning

confidence: 99%

“…146−148 Many mechanisms impair the fracture conductivity during the process of fracturing. 145,148,149 These include proppant embedment, 150 closure stress effect, 151,152 proppant crushing, 153,154 cyclic stress, 148 fine migration, 155 proppant pack diagenesis, 156,157 and the blockage caused by the gel residue in the proppant pack and gel filter cake at the fracture face. 158,159 Recent studies have demonstrated that the use of nanoparticles can improve and control formation damage during stimulation 8 compared to conventional methods.…”

Section: Wettability Alterationmentioning

confidence: 99%

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Review of Developments in Nanotechnology Application for Formation Damage Control

et al. 2021

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Formation damage has the potential to impair and weaken reservoir productivity and injectivity, causing substantial economic losses. Oil and gas wells can be damaged by various mechanisms, such as solid invasion, rock–fluid incompatibilities, fluid–fluid incompatibilities, and phase trapping/blocking, which can reduce natural permeability of oil and gas near the wellbore zone. These can happen during most field operations, including drilling operations, completion, production, stimulation, and enhanced oil recovery (EOR). Numerous studies have been undertaken in recent years on the application of nanotechnology to aid the control of formation damage. This review has found that nanotechnology is more successful than traditional materials in controlling formation damages in different phases of oil and gas development. This is facilitated by their small size and high surface area/volume ratio, which increase reactivity and interactivity to the adjacent materials/surfaces. Furthermore, adding hydrophilic nanoparticles (0.05 wt %) to surfactants during EOR alters their wettability from 15 to 33%. Wettability alteration capabilities of nanoparticles are also exemplified by carbonate rock from oil-wet to water-wet after the concentration of 4 g/L silica nanoparticles is added. In addition, mixing nanoparticles to the drilling fluid reduced 70% of fluid loss. However, the mechanisms of impairment of conductivity in shale/tight formations are not consistent and can differ from one formation to another as a result of a high level of subsurface heterogeneity. Thus, the reactivity and interaction of nanoparticles in these shale/tight formations have not been clearly explained, and a recommendation is made for further investigations. We also recommend more nanotechnology field trials for future research because deductions from current studies are insufficient. This review provides more insights on the applications of nanoparticles in different stages of oil and gas development, increasing our understanding on the measures to control formation damage.

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Section: Application Of Nanotechnology For Formation Damage Controlmentioning

confidence: 99%

Section: Wettability Alterationmentioning

confidence: 99%

Review of Developments in Nanotechnology Application for Formation Damage Control

et al. 2021

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“…Overview on Extension and Limitations of Macroscopic Darcy's Law for a Single and Multi-Phase Fluid Flow through a Porous Mediumas the wetting and non-wetting phase fluid pressures change dynamically. In such circumstances, the assumption of equilibrium capillary pressure as a function of the difference between the wetting and non-wetting fluid phase fluid pressures needs a relook 38…”

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confidence: 99%

An Overview on Extension and Limitations of Macroscopic Darcy’s Law for a Single and Multi-Phase Fluid Flow through a Porous Medium

2019

International Journal of Mining Science

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The flow of fluids through porous media is a topic of immense practical interest in a great diversity of technical field such as groundwater recovery and management, contaminant transport analysis, subsurface disposal of nuclear wastes, enhanced geothermal energy system, oil and gas production, thermal/chemical/biological enhanced oil recovery, hydraulic fracturing, CO 2 sequestration, combustion in inert porous matrix, flow through carbonate/fractured/shale-gas/CBM reservoirs, granular beds for the storage of solar energy, forced convection cooling and so on. Thus, characterizing fluid flow through a classical homogeneous porous medium; and subsequently, in a heterogeneous fractured reservoir has been the subject of immense interest in the context of groundwater aquifers (

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A new semi-analytical method for calculating well productivity near discrete fractures

Luo

Tang

Zhou

et al. 2018

Journal of Natural Gas Science and Engineering

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Impact of proppant diagenesis on shale gas productivity

Cited by 3 publications

References 0 publications

Review of Developments in Nanotechnology Application for Formation Damage Control

Review of Developments in Nanotechnology Application for Formation Damage Control

An Overview on Extension and Limitations of Macroscopic Darcy’s Law for a Single and Multi-Phase Fluid Flow through a Porous Medium

A new semi-analytical method for calculating well productivity near discrete fractures

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