Unveiling stimulation fluid-driven alterations in shale pore architecture through combined interpretation of TD-NMR and multi-component gas adsorption

Medina-Rodriguez, Bryan X.; Alvarado, Vladimir; Edgin, Matthew; Kaszuba, John P.

doi:10.1016/j.fuel.2021.120744

Cited by 7 publications

(11 citation statements)

References 69 publications

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“…Although CH 4 is not directly used for porosity or pore structure characterization, there is evidence that it can provide information regarding pore architecture alteration [43,85]. Furthermore, in Medina-Rodriguez et al [43], we demonstrated that if complementary techniques are combined, namely, TD-NMR and gas adsorption, it is possible to analyze changes in the surface properties of the rock wettability. Helium is probably the most used gas in the world for shale characterization.…”

Section: Adsorptive Capabilities and Selectionmentioning

confidence: 66%

“…Storage capacity and permeability measurements are the main properties of interest, meaning that performed experiments that involve the use of methane are related to the analysis of the behavior of this gas in porous media [34,[68][69][70][71][72][73][74][75][76][77][78][79][80][81][82][83][84]. Although CH 4 is not directly used for porosity or pore structure characterization, there is evidence that it can provide information regarding pore architecture alteration [43,85]. Furthermore, in Medina-Rodriguez et al [43], we demonstrated that if complementary techniques are combined, namely, TD-NMR and gas adsorption, it is possible to analyze changes in the surface properties of the rock wettability.…”

Section: Adsorptive Capabilities and Selectionmentioning

confidence: 99%

“…We define this process as the hybridization of gas adsorption. In previous research, we demonstrated that combination of gas adsorption and NMR can be used draw information regarding surface alteration [43]. Others have shown that these two techniques can be combined to understand the distribution of gasses in the pores and to gather information related to diffusion [153][154][155].…”

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confidence: 99%

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Use of Gas Adsorption and Inversion Methods for Shale Pore Structure Characterization

Medina-Rodriguez

Alvarado

2021

Energies

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The analysis of porosity and pore structure of shale rocks has received special attention in the last decades as unconventional reservoir hydrocarbons have become a larger parcel of the oil and gas market. A variety of techniques are available to provide a satisfactory description of these porous media. Some techniques are based on saturating the porous rock with a fluid to probe the pore structure. In this sense, gases have played an important role in porosity and pore structure characterization, particularly for the analysis of pore size and shapes and storage or intake capacity. In this review, we discuss the use of various gases, with emphasis on N2 and CO2, for characterization of shale pore architecture. We describe the state of the art on the related inversion methods for processing the corresponding isotherms and the procedure to obtain surface area and pore-size distribution. The state of the art is based on the collation of publications in the last 10 years. Limitations of the gas adsorption technique and the associated inversion methods as well as the most suitable scenario for its application are presented in this review. Finally, we discuss the future of gas adsorption for shale characterization, which we believe will rely on hybridization with other techniques to overcome some of the limitations.

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Section: Adsorptive Capabilities and Selectionmentioning

confidence: 66%

Section: Adsorptive Capabilities and Selectionmentioning

confidence: 99%

mentioning

confidence: 99%

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Use of Gas Adsorption and Inversion Methods for Shale Pore Structure Characterization

Medina-Rodriguez

Alvarado

2021

Energies

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“…The Wall Creek is an important unconventional reservoir; it produced over 180 million barrels of oil and nearly 450 billion cubic feet of gas since 1978 and up to 20 million barrels of oil and 90 billion cubic feet of gas may remain . We used the Wall Creek in this study as part of our broader effort − ,, to understand how hydraulic fracturing fluid and rock interact across a spectrum of unconventional reservoirs and lithologies. The bulk mineralogy of interbedded sandstone and mudstone in the Wall Creek is comparable to siliceous mudstones used in experiments with Marcellus Shale, Bakken Formation, and the Roseneath and Murteree Shales (Figure ; Supporting Information).…”

Section: Geologic Settingmentioning

confidence: 99%

Ionic Strength and pH Effects on Water–Rock Interaction in an Unconventional Siliceous Reservoir: On the Use of Formation Water in Hydraulic Fracturing

et al. 2021

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Hydraulic fracturing employs a mixture of freshwater and chemical additives. Substituting produced formation water for freshwater conserves freshwater resources, but formation water possessing a high ionic strength may damage formations and inhibit production. Hydrothermal experiments were conducted at reservoir conditions (115 °C, 35 MPa) to evaluate geochemical interactions between reservoir rock and hydraulic fracturing fluid synthesized using formation water. The specific hypotheses tested are (1) progressively greater ionic strength and acidity enhance the solubility of carbonate and aluminosilicate minerals and (2) acidity is more important than ionic strength for carbonate solubility but ionic strength is more important for aluminosilicate mineral solubility. Experiments replicated a shut-in well in the Wall Creek Member of the Cretaceous Frontier Formation, Powder River Basin, Wyoming , an important unconventional reservoir composed of low permeability sandstones interbedded with organic-rich mudstones. The core was reacted for ∼650 h (27 days) with (1) acidic hydraulic fracturing fluid (pH ∼ 2.3) mixed from formation water spanning two orders of magnitude ionic strength (0.016, 0.16, and 1.13 mol/kg) and (2) hydraulic fracturing fluid (ionic strength 0.11 mol/kg) of circumneutral pH (7.3). Reaction with hydraulic fracturing fluid of progressively greater ionic strength increased calcite solubility, but acidity was more important to calcite solubility than ionic strength. Trends of aqueous silica, potassium, and magnesium are consistent with the dissolution of feldspar and/or quartz and the precipitation of clay. Ionic strength was more important than acidity for feldspar–clay equilibrium, the predominant aluminosilicate mineral reaction. Hydraulic fracturing fluid with a progressively greater ionic strength contained larger amounts of aqueous silica, enhancing the potential importance of secondary clay mineralization. Mineralogic evidence for dissolution was limited to calcite and feldspar; no secondary clay was observed. Formation water may be used for hydraulic fracturing fluids, provided that the potential benefits and deleterious effects of calcite and feldspar dissolution and secondary clay mineralization are assessed on a case-by-case basis.

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“…Powder River Basin, Wyoming, USA 3 ; the Utica and Point Pleasant Shales of the Appalachian Basin, USA 17 ; and the Baxter Shale of the Green River Basin, USA 8,24 . Although not an unconventional reservoir, experiments have evaluated the Green River Shale of the Green River Basin, USA as a comparator to unconventional shale reservoirs 2,7,22 .…”

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confidence: 99%

Ionic Strength and pH Effects on WaterRock Interaction in an Unconventional Siliceous Reservoir: On the Use of Formation Water in Hydraulic Fracturing

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Unveiling stimulation fluid-driven alterations in shale pore architecture through combined interpretation of TD-NMR and multi-component gas adsorption

Cited by 7 publications

References 69 publications

Use of Gas Adsorption and Inversion Methods for Shale Pore Structure Characterization

Use of Gas Adsorption and Inversion Methods for Shale Pore Structure Characterization

Ionic Strength and pH Effects on Water–Rock Interaction in an Unconventional Siliceous Reservoir: On the Use of Formation Water in Hydraulic Fracturing

Ionic Strength and pH Effects on WaterRock Interaction in an Unconventional Siliceous Reservoir: On the Use of Formation Water in Hydraulic Fracturing

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