کد مقاله | کد نشریه | سال انتشار | مقاله انگلیسی | نسخه تمام متن |
---|---|---|---|---|
8863097 | 1620198 | 2018 | 10 صفحه PDF | دانلود رایگان |
عنوان انگلیسی مقاله ISI
Quantifying the extent of flowback of hydraulic fracturing fluids using chemical and isotopic tracer approaches
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کلمات کلیدی
موضوعات مرتبط
مهندسی و علوم پایه
علوم زمین و سیارات
ژئوشیمی و پترولوژی
پیش نمایش صفحه اول مقاله
چکیده انگلیسی
Hydraulic fracturing technologies have facilitated the rapid development of shale gas and other unconventional hydrocarbon resources throughout the world. Following hydraulic fracturing operations, a large quantity of water flows back to the surface. Understanding the provenance and composition of this returned water is therefore of paramount importance in order to optimize the recycling and reuse of the millions of litres of wastewater generated by hydraulic fracturing and to reduce freshwater consumption. Here we report flowback and produced fluids data obtained from a horizontal well in a low permeability reservoir within the Montney formation in Alberta, Canada. The reservoir was fractured with a mixture of nitrogen and water and the returned water was sampled 24 times during the first week of flowback and once after more than one year of production. The samples were analyzed for concentrations of major ions and for the stable isotope composition of water. The TDS (total dissolved solids) of the samples increased rapidly from 395â¯mg/L for the injected water to 50,000â¯mg/L after two days and 96,000â¯mg/L at the end of the first week of flowback. At the same time, δ2H values increased from â142â° to â113â° and δ18O values increased from â18.3â° to â9.8â°. After more than one year, TDS reached 204,000â¯mg/L while δ2H and δ18O values further increased to â68â° and + 2.7â°. The salinity of the returned water is shown to be the result of the mixing between the highly saline formation water initially present in the reservoir before hydraulic fracturing, with the fresh water used for hydraulic fracturing. The presented mathematical model allows the calculation of the amount of fracturing fluid recovered as well as the quantity of saline formation water produced and reveals that most of the injected water is imbibed in the host rock of the producing formation. After a week of flowback, only 18% of the injected water had been recovered, while the recovery of fracturing fluids after 14.5 months is estimated at 36% of the total volume injected.
ناشر
Database: Elsevier - ScienceDirect (ساینس دایرکت)
Journal: Applied Geochemistry - Volume 93, June 2018, Pages 20-29
Journal: Applied Geochemistry - Volume 93, June 2018, Pages 20-29
نویسندگان
F. Osselin, M. Nightingale, G. Hearn, W. Kloppmann, E. Gaucher, C.R. Clarkson, B. Mayer,