Formulating a novel drilling mud using bio-polymers, nanoparticles, and SDS and investigating its rheological behavior, interfacial tension, and formation damage

Abstract

Formation damage is a well-known problem that occurs during the exploration and production phases of the upstream sector of the oil and gas industry. This study aimed to develop a new drilling mud formulation by utilizing eco-friendly bio-polymers, specifically Carboxymethyl Cellulose (CMC), along with nanostructured materials and a common surfactant, sodium dodecyl sulfate (SDS). The rheological properties of the drilling fluid and the impact of additives on its properties were investigated at the micromodel scale, using a flow rate of 20 mL/h. The polymer concentration and nano clay concentration were set at two levels: 0.5 wt% and 1 wt%, respectively, while the surfactant content was varied at three levels: 0.1 wt%, 0.4 wt%, and 0.8 wt%. The results of the interfacial tension (IFT) analysis demonstrated a significant decrease in the interfacial tension between oil and water with the increasing concentration of SDS. Furthermore, following the API standard, the rheological behavior of the drilling fluid, including the gel strength and thixotropic properties of the mud, was evaluated with respect to temperature changes, as this is crucial for ensuring the inherent rheological stability of the mud. The rheological analysis indicated that the viscosity of the mud formulation with nanoparticles experienced a reduction of up to 10 times with increasing shear rate, while other formulations exhibited a decline of 100 times. Notably, the rheological properties of the Agar specimen improved at 150 °F due to its complete solubility in water, whereas other formulations exhibited a greater drop in viscosity at this temperature. As the temperature increased, drilling fluid containing nanostructured materials exhibited higher viscosity.

RETRACTED: On Improving Water-Based Drilling Mud Swelling Control Using Modified Poly(Vinyl Alcohol)s

“…Based on a recent work by Taghidimi et al (2023), samples of 1% carboxymethyl cellulose and agar on WBM at 49 and 65 °C exhibit the slightest reduction in viscosity compared to the sample without biopolymers. However, a 6 to 8 times viscosity drop of the samples between the 2 set temperatures shows the limitations of said biopolymers . In such cases, using more than a single viscosifier in a drilling formulation is often advised as it helps complement each of their limitations.…”

“…However, a 6 to 8 times viscosity drop of the samples between the 2 set temperatures shows the limitations of said biopolymers. 20 In such cases, using more than a single viscosifier in a drilling formulation is often advised as it helps complement each of their limitations. A similar work by Asma et al (2023) assessing optimization of partially hydrolyzed polyacrylamide (HPAM) in water-based drilling mud conducted at a higher temperature of 20° to 60 °C reported better rheological behavior at high concentrations (3%).…”

Comprehensive Review on the Recent Advancements in Nanoparticle-Based Drilling Fluids: Properties, Performance, and Perspectives

“…The rheological analysis reveals a reduction in viscosity up to 10 times with increasing shear rate for formulations containing nanoparticles, and a drop in viscosity of other formulations by 100 times. Notably, the viscosity of the Agar specimen improves at 65.5 °C, while other formulations exhibit a greater viscosity drop at this temperature …”

“…Notably, the viscosity of the Agar specimen improves at 65.5 °C, while other formulations exhibit a greater viscosity drop at this temperature. 118 Hamad et al developed a high-performance environmentally friendly silicate-based drilling fluid using cellulose NPs (CNPs) extracted from corncob at a low cost. Here, they used varied concentrations of cellulose NPs from 0.1 to 0.5 wt % by the weight of the drilling mud.…”