Influence of size and surface acidity of silica nanoparticles on inhibition of the formation damage by bentonite-free water-based drilling fluids. Part I: nanofluid design based on fluid-nanoparticle interaction

2019 ◽  
Vol 10 (4) ◽  
pp. 045020
Author(s):  
Johanna Vargas Clavijo ◽  
Leidy J Roldán ◽  
Laura Valencia ◽  
Sergio H Lopera ◽  
Richard D Zabala ◽  
...  
Keyword(s):  
Silica Nanoparticles ◽  
Surface Acidity ◽  
Free Water ◽  
Formation Damage ◽  
Drilling Fluids ◽  
Water Based

Effect of Silica Nanoparticles on Thermal Stability in Bentonite Free Water-Based Drilling Fluids to Improve its Rheological and Filtration Properties After Aging Process

2019 ◽  
Author(s):  
Johanna Vargas ◽  
Leidy Johanna Roldán ◽  
Sergio Hernando Lopera ◽  
José Carlo Cardenas ◽  
Richard Disney Zabala ◽  
...  
Keyword(s):  
Thermal Stability ◽  
Silica Nanoparticles ◽  
Aging Process ◽  
Free Water ◽  
Drilling Fluids ◽  
Water Based ◽  
Filtration Properties

scholarly journals Experimental study on thermal, rheological and filtration control characteristics of drilling fluids: effect of nanoadditives

2020 ◽  
Vol 75 ◽  
pp. 36
Author(s):  
Erfan Veisi ◽  
Mastaneh Hajipour ◽  
Ebrahim Biniaz Delijani
Keyword(s):  
Thermal Conductivity ◽  
Heat Capacity ◽  
Drilling Fluid ◽  
Formation Damage ◽  
Fluid Loss ◽  
Drilling Fluids ◽  
Drill Bit ◽  
Rheological Characteristics ◽  
Cu Nanoparticles ◽  
Water Based

Cooling the drill bit is one of the major functions of drilling fluids, especially in high temperature deep drilling operations. Designing stable drilling fluids with proper thermal properties is a great challenge. Identifying appropriate additives for the drilling fluid can mitigate drill-bit erosion or deformation caused by induced thermal stress. The unique advantages of nanoparticles may enhance thermal characteristics of drilling fluids. The impacts of nanoparticles on the specific heat capacity, thermal conductivity, rheological, and filtration control characteristics of water‐based drilling fluids were experimentally investigated and compared in this study. Al2O3, CuO, and Cu nanoparticles were used to prepare the water-based drilling nanofluid samples with various concentrations, using the two-step method. Transmission Electron Microscopy (TEM) and X-Ray Diffraction (XRD) were utilized to study the nanoparticle samples. The nanofluids stability and particle size distribution were, furthermore, examined using Dynamic Light Scattering (DLS). The experimental results indicated that thermal and rheological characteristics are enhanced in the presence of nanoparticles. The best enhancement in drilling fluid heat capacity and thermal conductivity was obtained as 15.6% and 12%, respectively by adding 0.9 wt% Cu nanoparticles. Furthermore, significant improvement was observed in the rheological characteristics such as the apparent and plastic viscosities, yield point, and gel strength of the drilling nanofluids compared to the base drilling fluid. Addition of nanoparticles resulted in reduced fluid loss and formation damage. The permeability of filter cakes decreased with increasing the nanoparticles concentration, but no significant effect in filter cake thickness was observed. The results reveal that the application of nanoparticles may reduce drill-bit replacement costs by improving the thermal and drilling fluid rheological characteristics and decrease the formation damage due to mud filtrate invasion.

A Brief Introduction to High Temperature and Foam Free Water Based Drilling Fluids

2016 ◽  
Author(s):  
Mojtaba Kalhor Mojammadi ◽  
Shervin Taraghikhah ◽  
Koroush Tahmasbi Nowtaraki
Keyword(s):  
High Temperature ◽  
Free Water ◽  
Drilling Fluids ◽  
Water Based

Influence of silica nanoparticles on the functionality of water-based drilling fluids

2019 ◽  
Vol 179 ◽  
pp. 504-512 ◽  
Author(s):  
Mortatha Al-Yasiri ◽  
Afrah Awad ◽  
Shahid Pervaiz ◽  
Dongsheng Wen
Keyword(s):  
Silica Nanoparticles ◽  
Drilling Fluids ◽  
Water Based

Loss Circulation and Formation Damage Control on Overbalanced Drilling With Different Formulations of Water Based Drill-In Fluids on Sandstone Reservoir

2012 ◽  
Author(s):  
Leandro F. Lopes ◽  
Bruno O. Silveira ◽  
Rosângela B. Z. L. Moreno
Keyword(s):  
Reverse Flow ◽  
Damage Control ◽  
Fluid Management ◽  
Formation Damage ◽  
Drilling Fluids ◽  
Reservoir Water ◽  
Well Productivity ◽  
Water Based ◽  
Permeability Impairment ◽  
Productivity Ratio

The oil well drilling should not damage formation, mainly the interest region: the reservoir. Drilling without damaging the reservoir is a hard challenge, and therefore the development of technologies and optimization process, including, for example, the design of fluids in order to minimize damage, is been stimulated. Drilling fluids may interact with reservoir rocks resulting on permeability impairment, which reduces well productivity. It has been reported that a detailed fluid management plan can help to minimize formation damage and improve well productivity. This work is focused on formation damage analysis due to drilling fluids invasion in high permeability sandstone oil reservoir. Water-based fluids were prepared with the following components: distilled water, salt (NaI), polymer (Partially Hydrolyzed Polyacrylamide - HPAM, and Xanthan Gum - XG) and clay (Bentonite). Samples were submitted to an invasion process, simulating an overbalanced drilling, and to an oil reverse flow, simulating oil production beginning. Results showed that all fluids containing clay presented less deep invasion than the fluids prepared with polymer only. Moreover, clay concentration influenced on permeability impairment and productivity ratio return results. HPAM fluids, when injected, invaded more deeply the samples than XG fluids, but productivity ratio return was also higher.

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