Geochemical Modeling of Iron (Hydr)oxide Scale Formation During Hydraulic Fracturing Operations

Li, Qingyun; Jew, Adam D.; Cercone, David; Bargar, John R.; Brown, Gordon E.; Maher, Kate

doi:10.15530/urtec-2019-612

Cited by 9 publications

(23 citation statements)

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“…At this stage, the only chemical reaction involving organic compounds is the release of bitumen from the shale matrix, which then aids in Fe(II) oxidation to Fe(III) . Detailed information about bitumen-aided Fe(II) oxidation and its application in modeling shale–fluid interactions is presented in our previous publication …”

Section: Methodsmentioning

confidence: 99%

“…The equilibrium constants were calculated from the CrunchFlow database, which is based on the SUPCRT92 database . Most of the kinetic values are adapted from our recent study, where a geochemical model was calibrated with time-resolved aqueous concentrations measured in a series of shale–fluid interaction experiments, where shale sands reacted with HFF in batch reactors. , In addition, a barite precipitation reaction is included on the basis of literature-reported rate constants and pH dependency. − The rate constants were then further fitted through model calibration.…”

Section: Methodsmentioning

confidence: 99%

“…Fe(II) oxidation has two pathways: one dependent upon pH and the other dependent upon bitumen extracted from shale by HFF. The rate for the pH-dependent pathway is known from literature (and was fixed during model calibration); the bitumen-aided Fe(II) oxidation rates were determined from calibrating a geochemical model with experimental data. , …”

Section: Methodsmentioning

confidence: 99%

“…3 Detailed information about bitumen-aided Fe(II) oxidation and its application in modeling shale−fluid interactions is presented in our previous publication. 37 The initial conditions for the shale domain (i.e., pre-reaction mineralogy and composition) differ for the Marcellus and Eagle Ford shale samples (Table 1), as determined from quantitative X-ray diffraction (XRD). In our experimental study, we identified the presence of an Fe(III)-bearing phase in pre-reaction Marcellus and Eagle Ford samples that was not detected via XRD, most likely because of its poor crystallinity.…”

Section: ■ Methodsmentioning

confidence: 99%

“…The rate for the pHdependent pathway is known from literature (and was fixed during model calibration); 42 the bitumen-aided Fe(II) oxidation rates were determined from calibrating a geochemical model with experimental data. 3,37 The mineral dissolution/precipitation reactions have rates of the form i k j j j j j j y…”

Section: ■ Methodsmentioning

confidence: 99%

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Reactive Transport Modeling of Shale–Fluid Interactions after Imbibition of Fracturing Fluids

Jew

Brown

et al. 2020

Energy Fuels

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Injection of hydraulic fracturing fluid (HFF) into shale formations for unconventional oil/gas production results in chemical reactions in the shale matrix. Our recent experimental study determined the depths to which different types of reactions between the shale matrix and the HFF extended. In the present study, we built continuum-scale reactive transport models to understand the coupling of chemical reactions and the transport of aqueous species in these shale–HFF systems. Calibration of the model with our previous experimental results reveals that it takes hours to months for the shale matrix to completely neutralize the imbibed acids, depending primarily upon the carbonate content of the shale. Both the HFF pH and pore pH affect the location of barite precipitation, resulting in unique barite precipitation profiles extending millimeters into calcite-rich Eagle Ford shale but only tens of micrometers into low-carbonate Marcellus shale. In addition, dissolved oxygen and extracted bitumen are key to reproducing the experimental observation of Fe(III) (oxyhydr)oxide formation in the shale matrix as a result of pyrite dissolution in the shales. A comparison between the modeling results of porosity in the present study to experimentally measured permeabilities in our previous study suggests that chemical reactions occurring at a greater depth than the observable reaction zone might have impacted permeability. Our model serves as a benchmark for efficiently modeling water–rock interactions in similar systems where bulk rock samples react with a solution in batch reactors. Important reactive transport processes were ascertained via modeling, which allows for quantitative prediction of shale–HFF interactions in shale matrices given the shale and HFF compositions.

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Section: Methodsmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

Section: ■ Methodsmentioning

confidence: 99%

Section: ■ Methodsmentioning

confidence: 99%

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Reactive Transport Modeling of Shale–Fluid Interactions after Imbibition of Fracturing Fluids

Jew

Brown

et al. 2020

Energy Fuels

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Mineral and fluid transformation of hydraulically fractured shale: case study of Caney Shale in Southern Oklahoma

Awejori,

Dong,

Doughty

et al. 2024

Geomech. Geophys. Geo-energ. Geo-resour.

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This study explores the geochemical reactions that can cause permeability loss in hydraulically fractured reservoirs. The experiments involved the reaction of powdered-rock samples with produced brines in batch reactor system at temperature of 95 °C and atmospheric pressure for 7-days and 30-days respectively. Results show changes in mineralogy and chemistry of rock and fluid samples respectively, therefore confirming chemical reactions between the two during the experiments. The mineralogical changes of the rock included decreases of pyrite and feldspar content, whilst carbonate and illite content showed an initial stability and increase respectively before decreasing. Results from analyses of post-reaction fluids generally corroborate the results obtained from mineralogical analyses. Integrating the results obtained from both rocks and fluids reveal a complex trend of reactions between rock and fluid samples which is summarized as follows. Dissolution of pyrite by oxygenated fluid causes transient and localized acidity which triggers the dissolution of feldspar, carbonates, and other minerals susceptible to dissolution under acidic conditions. The dissolution of minerals releases high concentrations of ions, some of which subsequently precipitate secondary minerals. On the field scale, the formation of secondary minerals in the pores and flow paths of hydrocarbons can cause significant reduction in the permeability of the reservoir, which will culminate in rapid productivity decline. This study provides an understanding of the geochemical rock–fluid reactions that impact long term permeability of shale reservoirs.

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Mineral Scales in Oil and Gas Fields

Hussein¹

2023

Essentials of Flow Assurance Solids in Oil and Gas Operations

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Geochemical Modeling of Iron (Hydr)oxide Scale Formation During Hydraulic Fracturing Operations

Cited by 9 publications

References 0 publications

Reactive Transport Modeling of Shale–Fluid Interactions after Imbibition of Fracturing Fluids

Reactive Transport Modeling of Shale–Fluid Interactions after Imbibition of Fracturing Fluids

Mineral and fluid transformation of hydraulically fractured shale: case study of Caney Shale in Southern Oklahoma

Mineral Scales in Oil and Gas Fields

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