Water-Rock Interaction for Eagle Ford, Marcellus, Green River, and Barnett Shale Samples

Ali, Maaz; Hasçakir, Berna

doi:10.2118/177304-ms

Cited by 15 publications

(3 citation statements)

References 21 publications

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“…Mineral compositions of shale reservoirs can vary significantly from carbonate-rich to silica-rich resulting in a wide variation of the pore size, porosity, permeability, and mechanical strength. ,,,,,− …”

Section: Shale Petrophysics and Geochemistrymentioning

confidence: 99%

“…However, at high ionic strengths (such as those observed in produced water), the ability for water to solvate ions becomes limited; the counterion effect can also be significant. Ali and Hascakir exposed crushed samples of Eagle Ford and Barnett shales to deionized water. The former has a higher proportion of gypsum compared to the latter but the results showed that the sulfate concentration in the two shales was similar.…”

Section: Evolution Of Shale Flow Channels Due To Reactive Transportmentioning

confidence: 99%

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A Critical Review of the Physicochemical Impacts of Water Chemistry on Shale in Hydraulic Fracturing Systems

Khan

Spielman-Sun

Jew

et al. 2021

Environ. Sci. Technol.

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Hydraulic fracturing of unconventional hydrocarbon resources involves the sequential injection of a high-pressure, particle-laden fluid with varying pH’s to make commercial production viable in low permeability rocks. This process both requires and produces extraordinary volumes of water. The water used for hydraulic fracturing is typically fresh, whereas “flowback” water is typically saline with a variety of additives which complicate safe disposal. As production operations continue to expand, there is an increasing interest in treating and reusing this high-salinity produced water for further fracturing. Here we review the relevant transport and geochemical properties of shales, and critically analyze the impact of water chemistry (including produced water) on these properties. We discuss five major geochemical mechanisms that are prominently involved in the temporal and spatial evolution of fractures during the stimulation and production phase: shale softening, mineral dissolution, mineral precipitation, fines migration, and wettability alteration. A higher salinity fluid creates both benefits and complications in controlling these mechanisms. For example, higher salinity fluid inhibits clay dispersion, but simultaneously requires more additives to achieve appropriate viscosity for proppant emplacement. In total this review highlights the nuances of enhanced hydrogeochemical shale stimulation in relation to the choice of fracturing fluid chemistry.

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Section: Shale Petrophysics and Geochemistrymentioning

confidence: 99%

Section: Evolution Of Shale Flow Channels Due To Reactive Transportmentioning

confidence: 99%

A Critical Review of the Physicochemical Impacts of Water Chemistry on Shale in Hydraulic Fracturing Systems

Khan

Spielman-Sun

Jew

et al. 2021

Environ. Sci. Technol.

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show abstract

“…Second, dissolution of the calcite in water results in an increase in calcium concentration which will adsorb to the DDL and therefore less water is needed to compensate for the negative charge of the clay in DDL. a.Data from Zhang et al (2015) b.Data from Ali and Hascakir (2015) SPE-180372-MS…”

Section: Investigation Of Clay Swelling Mechanismsmentioning

confidence: 99%

Mechanistic Modeling of Clay Swelling in Hydraulic Fractures Network

Sanaei

Shakiba

Varavei

et al. 2016

SPE Western Regional Meeting

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Hydraulic fracturing is the most effective technique used in the oil industry for economical production of hydrocarbon from very low permeability reservoirs. Recent experimental studies have indicated a change in hydraulic fractures (HF) conductivity as the result of the interactions between fracturing fluid and shale matrix. Clay swelling is one of the well-known undesirable interactions of this kind. If clay swelling occurs on the surface of hydraulic fractures, it can cause a major damage to the overall performance of the reservoir. Thus, a detailed understanding of clay stability issue is essential for fracturing fluid selection and operation planning.Clay swelling induced conductivity damage is primarily a function of rock mineralogy, fracturing fluid concentration, and formation brine salinity. Thus, various levels of clay-water interaction are expected in different shale formations. In this study, we present a mechanistic approach to model clay swelling in various rock mineralogies including Barnett (clay-rich), Eagle Ford (Calcite-rich), and Marcellus shales. Subsequently, we investigate the production loss due to clay swelling in a realistic complex hydraulic fracture network. We used UTCOMP_IPhreeqc, a coupled multi-phase reactive-transport simulator developed at The University of Texas at Austin, to comprehensively model this process. Expansion of double diffusive layer was assumed to be the main clay swelling mechanism. Surface complexation and ion exchange reactions were considered to capture the ion diffusion into the double diffusive layer. In each time step of the simulation, the volume expansion of clay materials exposed on the fracture surface was then used to modify the fracture aperture. In order to evaluate the performance of the complex hydraulic fracture network after clay swelling damage, the Embedded Discrete Fracture Model (EDFM) was applied.The simulation results indicate that the degree of clay swelling varies in different shale formations. Based on the clay content and the mineralogies that were considered in this work, a significant expansion in double diffusive layer was observed for the Barnett shale when fresh water was injected. However, this effect was much lower in Eagle Ford and Marcellus shales. Similarly, the production loss in the hydraulic fracture network was substantial in the Barnett example. The contribution of the fractures far from the producing well in gas production was negligible after clay swelling damage. The pressure depletion profiles clearly showed the adverse impact of conductivity damage on production performance. The presented approach provides the capability to accurately model the clay stability and to approximate its impact on transport properties of hydraulic fractures.

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2023

Reservoir Formation Damage

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Water-Rock Interaction for Eagle Ford, Marcellus, Green River, and Barnett Shale Samples

Cited by 15 publications

References 21 publications

A Critical Review of the Physicochemical Impacts of Water Chemistry on Shale in Hydraulic Fracturing Systems

A Critical Review of the Physicochemical Impacts of Water Chemistry on Shale in Hydraulic Fracturing Systems

Mechanistic Modeling of Clay Swelling in Hydraulic Fractures Network

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