Optimizing the Dispersion of Coal Fines Using Sodium Dodecyl Benzene Sulfonate

Awan, Faisal Ur Rahman; Keshavarz, Alireza; Akhondzadeh, Hamed; Nosrati, Ataollah; Al-Anssari, Sarmad; Iglauer, Stefan

doi:10.15530/ap-urtec-2019-198250

Cited by 9 publications

(6 citation statements)

References 28 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…We used a box size series of 2, 3, 4, 6, 8, 12, 16, 32 and 64; as can be seen in Table 3, whereby the coloured images were converted into a binary image [84]. The results validated the visual evidence as to the slope of 1.035 for pure quartz representing lack of HA on quartz surface and 1.62 for the highest concentration (i.e.…”

Section: Micro-scale Impact Of Humic Acid On Wettabilitymentioning

confidence: 65%

Effect of humic acid on CO2-wettability in sandstone formation

Ali

Awan

Ali

et al. 2021

Journal of Colloid and Interface Science

View full text Add to dashboard Cite

Section: Micro-scale Impact Of Humic Acid On Wettabilitymentioning

confidence: 65%

Effect of humic acid on CO2-wettability in sandstone formation

Ali

Awan

Ali

et al. 2021

Journal of Colloid and Interface Science

View full text Add to dashboard Cite

“…An optimum concentration of 0.05 wt % SDBS has been shown to optimize the stability of the nanoformulation (containing copper and alumina NPs) and also to reduce the particle size of nanoparticles over a wide pH range . Accordingly, in this research, we used the lowest tested SDBS concentration in the literature (0.01 wt %), , as can be seen in Table , and upon observing good results, reduced it further to 0.001 wt %.…”

Section: Methodsmentioning

confidence: 99%

“…In the current work, the SDBS surfactant is recommended for field applications to efficiently remove undesirable coal fines for the seams/proppant pack. This research is an extension on the application of surfactants to modify the surface properties of coal fines. ,,, However, 0.001 wt % SDBS acts as an effective dispersant where coal fines are <0.1 wt % in a saline (0.1 to 0.6 M NaCl) environment having a pH level of ∼8.5. It is suggested that further research be conducted on enhanced coal fines loading (up to 5 wt %), salinity as comparable to reservoir waters, high temperature and pressure for simulating the real coal seam conditions, micromorphology, nucleation kinetics of coal fines surfaces treated with surfactants, coal fines movement during gas flow (as has been conducted for shales , ), and facilities required at gathering systems for its optimization for continuous treatment (if desired).…”

Section: Recommendation and Suggestionsmentioning

confidence: 99%

Stable Dispersion of Coal Fines during Hydraulic Fracturing Flowback in Coal Seam Gas Reservoirs—An Experimental Study

et al. 2020

Self Cite

View full text Add to dashboard Cite

In subterranean coal seam gas (CSG) reservoirs, massive amounts of small-sized coal fines are released during the production and development stages, especially during hydraulic fracturing stimulation. These coal fines inevitably cause mechanical pump failure and permeability damage due to aggregation and subsequent pore-throat blockage. This aggregation behavior is thus of key importance in CSG production and needs to be minimized. Consequently, such coal fines dispersions need to be stabilized, which can be achieved by the formulation of improved fracturing fluids. Here, we thus systematically investigated the effectiveness of two additives (ethanol, 0.5 wt % and SDBS, 0.001 and 0.01 wt %) on dispersion stability for a wide range of conditions (pH 6−11; salinity of 0.1−0.6 M NaCl brine). Technically, the coal suspension flowed through a glass bead proppant pack, and fines retention was measured. We found that even trace amounts of sodium dodecyl benzene sulfonate (SDBS) (i.e., 0.001 wt %) drastically improved dispersion stability and reduced fines retention. The retention was further quantified by fractal dimensional analysis, which showed lower values for suspensions containing SDBS. This research advances current CSG applications and thus contributes to improved energy security.

show abstract

“…101 At pH 8, the stability of 0.2 wt % NP nanofluid is 20 ± 3 mV, confirming that the suspension is moderately stable. 102,103 However, at pH > 10, the dispersion stability of the nanoformulation is excellent. Hence, a more stable but highly viscous polymer-coated nanoformulation is suitable for EOR applications.…”

Section: Effect Of Salinitymentioning

confidence: 99%

Physicochemical Characterization of Zirconia Nanoparticle-Based Sodium Alginate Polymer Suspension for Enhanced Oil Recovery

et al. 2021

Self Cite

View full text Add to dashboard Cite

Biopolymers have been employed in enhanced oil recovery (EOR) due to their high viscosity and significant effects on waterflooding performance. Sodium alginate (NaAlg) is an excellent biopolymer that is extracted primarily from brown algae. It has been used in the biotechnology industry as a thickening agent, colloidal stabilizer, and oil recovery application. In the present study, a series of sodium alginate/zirconium oxide nanoparticle suspensions were prepared via solution mixing, and the effect of nanoparticle content, polymer concentration, temperature, salinity was investigated on the rheological behavior using a concentric cylinder dynamic rheometer. The rheology results revealed that the lower concentration of sodium alginates (0.01 to 0.06 wt %) and sodium alginate/nanoparticle suspensions (0.02 to 0.06 wt %) displayed shear thinning behavior for the whole range of shear rate from 0.1 to 100 s–1. It was noticed that the aging of the polymer/nanoparticle suspension at 25 °C for 7 days did not significantly affect the rheological characteristics. It was moreover observed that enhancing salinity from 0.015 to 0.1 wt % in the 0.04 wt % ZrO2 nanoparticle suspension comprising 0.1 wt % sodium alginate showed a progressive decrease in viscosity under the temperature range from 25 to 50 °C. The proposed sodium alginate/zirconium oxide nanoparticles from the mentioned results indicate their potential for enhanced oil recovery applications.

show abstract

Optimizing the Dispersion of Coal Fines Using Sodium Dodecyl Benzene Sulfonate

Cited by 9 publications

References 28 publications

Effect of humic acid on CO2-wettability in sandstone formation

Effect of humic acid on CO2-wettability in sandstone formation

Stable Dispersion of Coal Fines during Hydraulic Fracturing Flowback in Coal Seam Gas Reservoirs—An Experimental Study

Physicochemical Characterization of Zirconia Nanoparticle-Based Sodium Alginate Polymer Suspension for Enhanced Oil Recovery

Contact Info

Product

Resources

About