Effects of Nanoclay on the Rheological Properties and Resistivity of Synthetic Based Drilling Fluids under High Temperature

2018 ◽  
Author(s):  
Dongmei Pan ◽  
C. Vipulanandan ◽  
Niousha Amani ◽  
Sai Anudeep Reddy ◽  
Chella Ganapathy Chockalingam
Keyword(s):  
High Temperature ◽  
Rheological Properties ◽  
Drilling Fluids

Improving the rheological properties of water-based calcium bentonite drilling fluids using water-soluble polymers in high temperature applications

2021 ◽  
Vol 0 (0) ◽  
Author(s):  
Jinliang Liu ◽  
Fengshan Zhou ◽  
Fengyi Deng ◽  
Hongxing Zhao ◽  
Zhongjin Wei ◽  
...  
Keyword(s):  
High Temperature ◽  
Rheological Properties ◽  
Apparent Viscosity ◽  
Drilling Fluid ◽  
Shear Thickening ◽  
Water Soluble ◽  
Drilling Fluids ◽  
Drilling Depth ◽  
Filtration Loss ◽  
Calcium Bentonite

Abstract Most of bentonite used in modern drilling engineering is physically and chemically modified calcium bentonite. However, with the increase of drilling depth, the bottom hole temperature may reach 180 °C, thus a large amount of calcium bentonite used in the drilling fluid will be unstable. This paper covers three kinds of calcium bentonite with poor rheological properties at high temperature, such as apparent viscosity is greater than 45 mPa·s or less than 10 mPa·s, API filtration loss is greater than 25 mL/30 min, which are diluted type, shear thickening type and low-shear type, these defects will make the rheological properties of drilling fluid worse. The difference is attributed to bentonite mineral composition, such as montmorillonite with good hydration expansion performance. By adding three kinds of heat-resistant water-soluble copolymers Na-HPAN (hydrolyzed polyacrylonitrile sodium), PAS (polycarboxylate salt) and SMP (sulfomethyl phenolic resin), the rheological properties of calcium bentonite drilling fluids can be significantly improved. For example, the addition of 0.1 wt% Na-HPAN and 0.1 wt% PAS increased the apparent viscosity of the XZJ calcium bentonite suspension from 4.5 to 19.5 mPa·s at 180 °C, and the filtration loss also decreased from 20.2 to 17.8 mL.

scholarly journals High temperature and high pressure rheological properties of high-density water-based drilling fluids for deep wells

2012 ◽  
Vol 9 (3) ◽  
pp. 354-362 ◽  
Author(s):  
Fuhua Wang ◽  
Xuechao Tan ◽  
Ruihe Wang ◽  
Mingbo Sun ◽  
Li Wang ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Rheological Properties ◽  
High Density ◽  
Drilling Fluids ◽  
Deep Wells ◽  
Water Based

scholarly journals The application of MWCNT to enhance the rheological behavior of drilling fluids at high temperature

2017 ◽  
Vol 12 (3) ◽  
Author(s):  
Abdul Razak Ismail ◽  
W. R. W Sulaiman ◽  
M. Z. Jaafar ◽  
A. Aftab ◽  
A. A. Razi ◽  
...  
Keyword(s):  
High Temperature ◽  
Rheological Properties ◽  
Rheological Behavior ◽  
Oil And Gas ◽  
Drilling Fluid ◽  
Gel Strength ◽  
Drilling Fluids ◽  
Deep Wells ◽  
Multi Walled Carbon Nanotube ◽  
Filtrate Loss

Drilling fluid is the key component to drill oil and gas wells. The rheological behavior of drilling fluid will be affected when drilling deep wells especially at high temperature and high pressure reservoir. This research was conducted to study the effect of the nanoparticles over the rheological properties of the drilling fluid when aging at high temperature condition. Several drilling fluids were prepared using synthetic based fluids (Sarapar and Saraline) to study the effect of multi-walled carbon nanotube (MWCNT) at different concentrations. The rheological properties of drilling fluid were analyzed after aging at 250 °F and 350 °F for 16 hours. The results revealed that the addition of MWCNT improved the 10-sec gel strength by 33% and filtrate loss volume was reduced to 10% after aging at 250°F in Saraline drilling fluid. Moreover, the plastic viscosity of Saraline and Sarapar drilling fluid after addition of MWCNT was enhanced by 6% and 27% at 350 °F. Filtrate loss volume of Sarapar drilling fluid was reduced by 19 % after aging at 250 °F for 16 hours. The overall results showed that the addition of MWCNT into the drilling fluid have slightly improved the rheological properties of drilling fluids under high temperature conditions.

scholarly journals Study on the Rheological Properties of Ultra-High Temperature CGA Drilling Fluids

2021 ◽  
Author(s):  
Wenxi Zhu ◽  
Xiuhua Zheng
Keyword(s):  
High Temperature ◽  
Rheological Properties ◽  
High Temperatures ◽  
Drilling Fluid ◽  
Drilling Fluids ◽  
Underbalanced Drilling ◽  
Deep Wells ◽  
Colloidal Gas Aphron ◽  
Oil Gas ◽  
Ultra High Temperature

Colloidal gas aphron (CGA) drilling fluids are a kind of environmentally-friendly underbalanced drilling technique, which has attracted more attention in depleted reservoirs and other low-pressure areas. With the shortage of global oil/gas resources, drilling has gradually shifted to high-temperature and deep wells. Hence, a study on the ultra-high temperature rheology properties of CGA fluids is lacking and urgently needed. In this study, a novel CGA drilling fluid system was prepared by modified starch and amino acid surfactant, and rheological properties after 120-300°C aged was investigate. Results show that: (1) Herschel-Bulkley model is the preferred model to predict CGA drilling fluid at ultra-high temperatures; (2) It was proved that CGA drilling fluid is a high-quality drilling fluid with extremely high value of LSRV and shear thinning property within 280°C. Compared to the traditional XG-based CGA drilling fluid, the improvement of LSRV at ultra-high temperatures is a significant advantage of EST-based CGA drilling fluid which is conducive to carrying cuttings and sealing formation pores.

Anisotropic Nano-Platelets to Develop Gel Strength at High Temperature in Aqueous Fluids

2021 ◽  
Author(s):  
Hasmukh Patel ◽  
Gadam Myratgeldiyev
Keyword(s):  
High Temperature ◽  
Rheological Properties ◽  
Sol Gel ◽  
Aqueous Dispersion ◽  
Ionic Species ◽  
Aqueous System ◽  
Gel Strength ◽  
Drilling Fluids ◽  
Higher Temperature ◽  
Covalently Linked

Abstract Aqueous fluids also refer as water-based drilling muds (WBMs) have considered as the most favorable WBMs, owing to their inherent advantages such as economically viability and environmentally benign characteristics. The major problems WBMs encountered is thinning of drilling fluids while drilling under high pressure high temperature. The detrimental rheological properties of WBMs under HPHT result into pipe sticking, low rate of penetration of the drill bit and requirement of high torque for drilling operations. The hydrophilic clays have been employed as viscosifiers in WBMs to maintain the rheological properties, albeit, their viscosifying characteristics have hindered in the presence of ionic species in the aqueous system at high temperature. These shortcomings can be tackled by developing an additive that can exhibit neutral surface changes and ability to undergo gelation at higher temperature. We have developed an additive functionalized with polar groups on anisotropic nano-platelets (LMS) through sol-gel technique. Spectroscopic and crystallographic characterization of LMS have proved the formation of layered structures with covalently linked polar functionalities. The viscoelastic studies were conducted on aqueous dispersion of these nano-platelets at different temperature, which revealed an unprecedented phenomenon -increase in gel strength at higher temperature, a key property required for ideal WBMs. LMS nano-platelet has shown formation of network structure in aqueous medium to boost storage modulus of the fluid. This additive can overcome the demerits associated with natural hydrophilic layered silicates and improve the rheological properties under challenging well conditions.

Rheological properties of oil-based drilling fluids at high temperature and high pressure

2008 ◽  
Vol 15 (S1) ◽  
pp. 457-461 ◽  
Author(s):  
Sheng-ying Zhao ◽  
Jie-nian Yan ◽  
Yong Shu ◽  
Hong-xia Zhang
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Rheological Properties ◽  
Drilling Fluids

Rheological Properties of Water-Based Drilling Fluids in Deep Offshore Conditions

2019 ◽  
Author(s):  
Qian Ding ◽  
Baojiang Sun ◽  
Zhiyuan Wang ◽  
Yonghai Gao ◽  
Yu Gao ◽  
...  
Keyword(s):  
High Pressure ◽  
High Temperature ◽  
Low Temperature ◽  
Rheological Properties ◽  
Apparent Viscosity ◽  
Drilling Fluid ◽  
Plastic Viscosity ◽  
Drilling Fluids ◽  
Water Based ◽  
Temperature And Pressure

Abstract In deep-water drilling, the drilling fluid is affected by the alternating temperature field derived from the low temperature of the seawater and the high temperature of the formation. The complicated wellbore temperature and pressure environments make the prediction of rheological properties of the drilling fluid difficult. In this study, the rheological properties of water-based drilling fluid in full temperature and pressure range of deep-water conditions were tested from 2 to 150 °C (35.6 to 302 °F) and 0.1 to 70 MPa (14.5 to 10000psi). The experiment was carried out by the OFI130-77 high temperature and high pressure rheometer. The experimental data were processed by multiple regression analysis method, and the mathematical model for predicting the apparent viscosity, plastic viscosity and yield point of water-based drilling fluid under high temperature and high pressure conditions was established. The experimental results show that when the temperature is lower than 65 °C (149 °F), the apparent viscosity and plastic viscosity of the water-based drilling fluid decrease significantly with increasing temperature. When the temperature is higher than 65 °C (149 °F), the apparent viscosity and plastic viscosity decrease slowly. Under low temperature conditions, the effect of pressure on the apparent viscosity and plastic viscosity of water-based drilling fluids is relatively significant. The calculated values of the prediction model have a good agreement with the experimental measurements. Compared with the traditional model, this prediction model has a significant improvement in the prediction accuracy in the low temperature section, which can provide a calculation basis for on-site application of deepwater drilling fluid.

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