Effect of Pyrite Oxidation on Flowback Water Properties During Hydraulic Fracturing in Calcite-Rich Shales

2020 ◽  
Author(s):  
Lingping Zeng ◽  
Muhammad Atif Iqbal ◽  
Nathan Reid ◽  
Christopher Lagat ◽  
Md Mofazzal Hossain ◽  
...  
Keyword(s):  
Hydraulic Fracturing ◽  
Pyrite Oxidation ◽  
Flowback Water ◽  
Water Properties

scholarly journals Direct Evidence of Salinity and pH Effects on the Interfacial Interactions of Asphaltene-Brine-Silica Systems

Molecules ◽  
2020 ◽  
Vol 25 (5) ◽  
pp. 1214 ◽  
Author(s):  
Fanghui Liu ◽  
Hui Yang ◽  
Ting Chen ◽  
Shanmeiyu Zhang ◽  
Danfeng Yu ◽  
...  
Keyword(s):  
Zeta Potential ◽  
Hydraulic Fracturing ◽  
Silica Surface ◽  
Adhesion Force ◽  
Ph Value ◽  
Complex Function ◽  
Intermolecular Forces ◽  
Ph Effects ◽  
Water Recovery ◽  
Flowback Water

The hydraulic fracturing technique remains essential to unlock fossil fuel from shale oil reservoirs. However, water imbibed by shale during hydraulic fracturing triggers environmental and technical challenges due to the low flowback water recovery. While it appears that the imbibition of fracturing fluid is a complex function of physico-chemical processes in particular capillary force which is associated with wettability of oil-brine-shale, the controlling factor(s) to govern the wettability is incomplete and the literature data in this context is missing. We thus measured the adsorption/desorption of asphaltenes on silica surface in the presence of brines using quartz crystal microbalance with dissipation (QCM-D). We detected zeta potential of asphaltene-brine and brine-silica systems and calculated the disjoining pressures of the asphaltene-brine-silica system in the case of different salinity. Moreover, we performed a geochemical study to quantify the variation of surface chemical species at asphaltene and silica surfaces with different pH values and used the chemical force microscope (CFM) method to quantify the effect of pH on intermolecular forces. Our results show that lowering salinity or raising pH reduced the adhesion force between asphaltene and silica surface. For example, at a pH value of 6.5, when the concentration of injected water is reduced from 1000 mM to 100 mM and 10 mM, the adhesion force decreased by approximately 58% and 66%, respectively. In addition, for the 100 mM NaCl solution, when the pH value increased from 4.5 to 6.5 and 9, the adhesion force decreased by approximately 56% and 87%, respectively. Decreased adhesion forces between asphaltene and the silica surface could promote the desorption of asphaltene from the silica surface, resulting in a negative zeta potential for both asphaltene-silica and brine-silica interfaces and a shift of wettability towards water-wet characteristic. During such a process, -NH+ number at asphaltene surfaces decreases and the bonds between -NH+ and >SiO− break down, to further interpret the formation of a thinner asphaltene adlayer on the rock surface. This study proposes a reliable theoretical basis for the application of hydraulic fracturing technology, and a facile and possible manipulation strategy to increase flowback water from unconventional reservoirs.

Electricity from methanol using indigenous methylotrophs from hydraulic fracturing flowback water

2020 ◽  
Vol 135 ◽  
pp. 107549 ◽  
Author(s):  
Kalimuthu Jawaharraj ◽  
Namita Shrestha ◽  
Govind Chilkoor ◽  
Bhuvan Vemuri ◽  
Venkataramana Gadhamshetty
Keyword(s):  
Hydraulic Fracturing ◽  
Flowback Water

The anodic potential shaped a cryptic sulfur cycling with forming thiosulfate in a microbial fuel cell treating hydraulic fracturing flowback water

2020 ◽  
Vol 185 ◽  
pp. 116270
Author(s):  
Xiaoting Zhang ◽  
Daijun Zhang ◽  
Yongkui Huang ◽  
Shanshan Wu ◽  
Peili Lu
Keyword(s):  
Fuel Cell ◽  
Hydraulic Fracturing ◽  
Microbial Fuel Cell ◽  
Sulfur Cycling ◽  
Flowback Water ◽  
Anodic Potential

Characterization of hydraulic fracturing flowback water in Colorado: Implications for water treatment

2015 ◽  
Vol 512-513 ◽  
pp. 637-644 ◽  
Author(s):  
Yaal Lester ◽  
Imma Ferrer ◽  
E. Michael Thurman ◽  
Kurban A. Sitterley ◽  
Julie A. Korak ◽  
...  
Keyword(s):  
Water Treatment ◽  
Hydraulic Fracturing ◽  
Flowback Water

scholarly journals Polyacrylamide in hydraulic fracturing fluid causes severe membrane fouling during flowback water treatment

2018 ◽  
Vol 560 ◽  
pp. 125-131 ◽  
Author(s):  
Boya Xiong ◽  
Selina Roman-White ◽  
Bethany Piechowicz ◽  
Zachary Miller ◽  
Benjamin Farina ◽  
...  
Keyword(s):  
Water Treatment ◽  
Hydraulic Fracturing ◽  
Membrane Fouling ◽  
Fracturing Fluid ◽  
Flowback Water ◽  
Hydraulic Fracturing Fluid

scholarly journals Reuse of Flowback Water from Hydraulic Fracturing for Drilling Mud Preparation and Secondary Hydrocarbon Recovery

Energies ◽  
2021 ◽  
Vol 14 (18) ◽  
pp. 5921
Author(s):  
Ewa Knapik ◽  
Katarzyna Chruszcz-Lipska ◽  
Łukasz Łukańko ◽  
Sławomir Wysocki
Keyword(s):  
Hydraulic Fracturing ◽  
Oil Recovery ◽  
Drilling Mud ◽  
Hydrocarbon Recovery ◽  
Flowback Water ◽  
Beneficial Reuse ◽  
Drilling Operations ◽  
Secondary Oil Recovery ◽  
Drilling Muds ◽  
Coagulation And Filtration

Flowback water after completion of hydraulic fracturing is one of major waste streams generated during the lifespan of a well so its beneficial reuse is crucial. The application of treated flowback is not limited to stimulation processes but also may include drilling operations and secondary oil recovery. The flowback water used in this work is characterized by high salinity reaching up to ~295 g/L caused mainly by NaCl. The presence of suspended solids, mainly corrosion products, prompts the use of coagulation and filtration as treatment methods. Among tested coagulants the most effective one was the SAX18 (NaAlO2) commercial coagulant applied at concentration of 12 mL/L which reduces the water turbidity from over 400 FTU to 23 FTU. The applied treatment greatly reduces the concentration of scaling ions and so the concentration of SiO2 is reduced by 64%, Ba2+–66%, Fe2–36%, Mn2+–65%, SO42−–66%. The treated flowback fluid can be reused in surfactant flooding for enhanced oil recovery where achieves 7% higher displacing efficiency than fresh water. The drilling muds which were prepared using the untreated flowback water exhibit good rheological properties. The obtained results show that recycling of flowback water in future drilling and exploitation operations is technically feasible.

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