The Development of a Viscosifier for Clay Free and Water Based Drilling Fluid With High Density and High Temperature Resistant

2016 ◽  
Author(s):  
X. M. Zhang ◽  
G. C. Jiang ◽  
Y. Xuan ◽  
L. Wang ◽  
X. B. Huang
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
High Density ◽  
Water Based

scholarly journals Thermoresponsive Bentonite for Water-Based Drilling Fluids

Materials ◽  
2019 ◽  
Vol 12 (13) ◽  
pp. 2115 ◽  
Author(s):  
Dong ◽  
Pu ◽  
Ren ◽  
Zhai ◽  
Gao ◽  
...  
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Environmental Scanning Electron Microscopy ◽  
High Density ◽  
Drilling Fluids ◽  
Isothermal Adsorption ◽  
Mud Cake ◽  
Water Based ◽  
Recovery Behavior ◽  
Increasing Temperature

As an important industrial material, bentonite has been widely applied in water-based drilling fluids to create mud cakes to protect boreholes. However, the common mud cake is porous, and it is difficult to reduce the filtration of a drilling fluid at high temperature. Therefore, this paper endowed bentonite with a thermo response via the insertion of N-isopropylacrylamide (NIPAM) monomers. The interaction between NIPAM monomers and bentonite was investigated via Fourier infrared spectroscopy (FTIR), isothermal adsorption, and X-ray diffraction (XRD) at various temperatures. The results demonstrate that chemical adsorption is involved in the adsorption process of NIPAM monomers on bentonite, and the adsorption of NIPAM monomers accords with the D–R model. With increasing temperature, more adsorption water was squeezed out of the composite when the temperature of the composite exceeded 70 °C. Based on the composite of NIPAM and bentonite, a mud cake was prepared using low-viscosity polyanionic cellulose (Lv-PAC) and initiator potassium peroxydisulfate (KPS). The change in the plugging of the mud cake was investigated via environmental scanning electron microscopy (ESEM), contact angle testing, filtration experiments, and linear expansion of the shale at various temperatures. In the plugging of the mud cake, a self-recovery behavior was observed with increasing temperature, and resistance was observed at 110 °C. The rheology of the drilling fluid was stable in the alterative temperature zone (70–110 °C). Based on the high resistance of the basic drilling fluid, a high-density drilling fluid (ρ = 2.0 g/cm3) was prepared with weighting materials with the objective of drilling high-temperature formations. By using a high-density drilling fluid, the hydration expansion of shale was reduced by half at 110 °C in comparison with common bentonite drilling fluid. In addition, the rheology of the high-density drilling fluid tended to be stable, and a self-recovery behavior was observed.

Rheology and fluid loss of a polyacrylamide-based micro-gel particles in a water-based drilling fluid

2020 ◽  
Vol 10 (5) ◽  
pp. 657-662
Author(s):  
Gang Wang ◽  
Honghai Fan ◽  
Guancheng Jiang ◽  
Wanjun Li ◽  
Yu Ye ◽  
...  
Keyword(s):  
Particle Size ◽  
High Temperature ◽  
Particle Size Distribution ◽  
Size Distribution ◽  
Drilling Fluid ◽  
Crosslinking Agent ◽  
Fluid Loss ◽  
Temperature Property ◽  
Water Based ◽  
The Cross

In this paper, the cross-linked micro-gel polymer between acrylamide (AM) and N, N-Methylenebisacrylamide (MBA) was synthesized by dispersion polymerization. The initiator and crosslinking agent concentration were used to control the particle size of micro-gel polymer. The filtration property and mechanism of micro-gel were investigated comprehensively. The characteristics of micro-gel were checked by means of Fourier transform infrared spectroscopy, thermogravimetry, transmission electron microscopy, and particle size distribution, respectively. The results indicated that the cross-linked micro-gel polymer exhibited several outstanding merits, such as thermal stability (up to 200 °C), filtration control and rheological property. Microstructure analysis and particle size distribution examinations showed that the scale of micro-gel polymer was micro, which is in accord with design. Rheological tests demonstrated that the nonlinear structure of micro-gel polymer showed less impact on the apparent viscosity. The anti-high temperature property of micro-gel polymer was better than poly anioniccellulose (PAC) and asphalt widely applied in drilling fluid for anti-high temperature fluid-loss additive. As a result, the cross-linked micro-gel polymer had great potential to be applied in high temperature water-based mud.

Hydrophobic‐associated polymer‐based laponite nanolayered silicate composite as filtrate reducer for water‐based drilling fluid at high temperature

2019 ◽  
Vol 137 (18) ◽  
pp. 48608 ◽  
Author(s):  
Haokun Shen ◽  
Kaihe Lv ◽  
Xianbin Huang ◽  
Jingping Liu ◽  
Yingrui Bai ◽  
...  
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Water Based

scholarly journals Effect of Cycloaliphatic Amine on the Shale Inhibitive Properties of Water-Based Drilling Fluid

2015 ◽  
Vol 8 (1) ◽  
pp. 19-27 ◽  
Author(s):  
Hanyi Zhong ◽  
Dong Sun ◽  
Weian Huang ◽  
Yunfeng Liu ◽  
Zhengsong Qiu
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Hardness Test ◽  
Drilling Fluids ◽  
The Novel ◽  
Potential Measurement ◽  
Clay Particles ◽  
Water Based ◽  
Bulk Hardness ◽  
Dispersion Test

In order to improve the inhibitive properties and high temperature resistance of shale inhibitor, cycloaliphatic amines were introduced as shale hydration inhibitors in water-based drilling fluids. Bulk hardness test, shale cuttings dispersion test, bentonite inhibition test and water adsorption test were carried out to characterize the inhibitive properties of the novel amines. Surface tension measurement, zeta potential measurement, XRD, contact angle test, SEM and TGA were performed to investigate the interaction between the cycloaliphatic amines and clay particles. The results indicated that cycloaliphatic amines exhibited superior inhibitive properties to the state of the art inhibitors. Moreover, the amines were high temperature resistant. The hydrophobic amine could intercalate into the clay gallery with monolayer orientation. The protonated ammonium ions neutralized the negatively charged surface. After adsorption, the hydrophobic segment covered the clay surface and provided a shell preventing the ingress of water.

A Novel Water-Based Drilling Fluid Tailored for Challenging Slanted HTHP Wells

2021 ◽  
Author(s):  
Vaughn Reza Traboulay ◽  
Tint Htoo Aung ◽  
Cedric Manzoleloua ◽  
Balakrishnan Panamarathupalayam ◽  
Carmelo Arena ◽  
...  
Keyword(s):  
High Temperature ◽  
Drilling Fluid ◽  
Synthetic Polymer ◽  
Term Stability ◽  
Long Term Stability ◽  
High Temperature Water ◽  
Water Based ◽  
Static Conditions ◽  
Temperature Water

Abstract High-temperature water-based drilling fluid systems hold several advantages over synthetic based systems from financial and environmental viewpoints. However, most conventional water-based systems start to become unstable at temperatures above 300 degF. This paper details the design and implementation of A Novel Water-Based Drilling Fluid that meet these temperature stability requirements. The newly developed high-temperature water-based system discussed in this paper utilizes a custom-made branched synthetic polymer that exhibits superior rheological properties and fluid loss control as well as long term stability above 400 degF. The branched synthetic polymer is compatible with most oilfield brines and maintains excellent low-end rheology necessary for hole cleaning and solids suspension under high-temperatures and pressures. Under static conditions, the high-temperature fluid shows no gelation resulting in lower swab surge pressures while the stability of the highly branched synthetic polymer and enhanced rheological profile minimize sag. To drill a challenging exploration well, a Middle East client required a cost-effective drilling fluid system which remains stable under static temperatures expected to exceed 375 degF. The long-term stability of the system was critical for successful wireline logging operations. In addition, the system was required to provide shale inhibition, hydrogen sulfide suppression and sufficient density (above 16.5 lbm/galUS) to maintain well integrity while drilling through anticipated high-pressure zones. The challenging intermediate (12.25-in and 8.375-in) and reservoir (6-in) sections were successfully drilled and evaluated using this new branched synthetic polymer-based system. Fluid property trends and system treatments will be detailed alongside thermal stability data for extended periods required for wireline logging (up to 9 days static). This paper will discuss how proper laboratory design of the high-temperature water-based system was translated to excellent field performance and will indicate how this technology can be utilized for future campaigns in the region and worldwide.

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