Effect of maturity and mineralogy on fluid-rock reactions in the Marcellus Shale

Journal Article · 01 January 2019 · Environmental Science: Processes & Impacts

DOI: https://doi.org/10.1039/C8EM00452H · OSTI ID:1569814

Pilewski, John ^[1]; Sharma, Shikha  ^[1]; Agrawal, Vikas  ^[1]; Hakala, J. Alexandra  ^[2]; Stuckman, Mengling Y. ^[2]

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1. West Virginia Univ., Morgantown, WV (United States)
2. National Energy Technology Lab. (NETL), Pittsburgh, PA, (United States)

Natural gas extraction from the Appalachian Basin has significantly increased in the past decade. The push to properly dispose, reuse, or recycle the large amounts of produced fluids associated with hydraulic fracturing operations and design better fracturing fluids has necessitated a better understanding of the subsurface chemical reactions taking place during hydrocarbon extraction. Using autoclave reactors, this study mimics the conditions of deep subsurface shale reservoirs to observe the chemical evolution of fluids during the shut-in phase of hydraulic fracturing (HF), a period when hydraulic fracturing fluids (HFFs) remain confined in the reservoir. The experiment was conducted by combining a synthetic hydraulic fracturing fluid and powdered shale core samples in high temperature/pressure static autoclave reactors for 14 days. Shale samples of varying maturity and mineralogy were used to assess the effect of these variations on the proliferation of inorganic ions and low molecular weight volatile organic compounds (VOCs), mainly benzene, toluene, ethylbenzene and xylenes (BTEX) and monosubstituted carboxylic acids. Ion chromatography results indicate that the relative abundance of ions present was similar to that of water produced from HF operations in the Marcellus Shale basin. There was an increase of SO₄^2- and PO₄^3- and a decrease in Ba²⁺ upon fluid-shale reaction. Major ionic shifts indicate calcite dissolution in two of the fluid-shale reactions and barite precipitation in all fluid-shale reactions. Toluene, xylene, and carboxylic acids were produced in the shale-free control experiment. The most substantial increase in BTEX analytes was observed in reactions with low maturity shale, while the high maturity shale reaction produced no measurable BTEX compounds. Total organic carbon decreased in all reactions including fracturing fluid and shale, suggesting adsorption onto the organic matter (OM) matrix. The results from this study highlight that both the nature of OM and mineralogy play a key role in determining the fate of inorganic and organic compounds during fluid–shale interactions in the subsurface shale reservoir. Overall this study aims to contribute to the growing understanding of complex chemical interactions that occur in the shale reservoirs during HF, which is vital for determining the potential environmental impacts of HF and designing more efficient HFF and produced water recycling techniques for environmentally conscious natural gas production.

• Research Organization: National Energy Technology Laboratory (NETL), Pittsburgh, PA, Morgantown, WV, and Albany, OR (United States)
• Sponsoring Organization: USDOE Office of Fossil Energy (FE)
• Grant/Contract Number: 89243318CFE000003
• OSTI ID: 1569814
• Journal Information: Environmental Science: Processes & Impacts, Journal Name: Environmental Science: Processes & Impacts Journal Issue: 5 Vol. 21; ISSN 2050-7887; ISSN ESPICZ
• Publisher: Royal Society of ChemistryCopyright Statement
• Country of Publication: United States
• Language: English