Open AccessNumerical Analysis of the Source of Excessive Na+ and Cl- Species in Flowback Water From Hydraulically Fractured Shale Formations
Author(s) -
Maxian B. Seales,
Robert Dilmore,
Turgay Ertekin,
John Yilin Wang
Publication year - 2016
Publication title -
spe journal
Language(s) - English
Resource type - Journals
SCImago Journal Rank - 1.062
H-Index - 101
eISSN - 1930-0220
pISSN - 1086-055X
DOI - 10.2118/180911-pa
Subject(s) - halite , dissolution , hydraulic fracturing , produced water , total dissolved solids , brine , geology , oil shale , mineralogy , chemistry , petroleum engineering , gypsum , environmental engineering , environmental science , paleontology , organic chemistry
Summary Fracture fluid is composed of fresh water, proppant, and a small percentage of other additives, which support the hydraulic-fracturing process. Excluding situations in which flowback water is recycled and reused, the total dissolved solids in fracture fluid is limited to the fluid additives, such as potassium chloride (1 to 7 wt% KCL), which is used as a clay stabilizer to minimize clay swelling and clay-particle migration. However, the composition of recovered fluid, especially as it relates to the total dissolved solids (TDS), is always substantially different from the injected fracture fluid. The ability to predict flowback-water volume and composition is useful when planning for the management or reuse of this aqueous byproduct stream. In this work, an ion-transport and halite-dissolution model was coupled with a fully implicit, dual-porosity, numerical simulator to study the source of the excess solutes in flowback water and to predict the concentration of both Na+ and Cl− species seen in recovered water. The results showed that mixing alone, between the injected fracture fluid and concentrated in-situ formation brine, could not account for the substantial rise in TDS seen in flowback water. Instead, the results proved that halite dissolution is a major contributor to the change in TDS seen in fracture fluid during injection and recovery. Halite dissolution can account for as much as 81% of Cl− and 86.5% of Na+ species seen in 90-day flowback water; mixing, between the injected fracture fluid and in-situ concentrated brine, accounts for approximately 19% of Cl− and 13% of Na+.