Rectorite drilling fluid: high-temperature resistance for geothermal applications
Introduction
Researchers worldwide are currently engaged in the active development of geothermal resource applications (Esen et al., 2013). For example, a vertical ground-source heat pump with a U-tube borehole heat exchanger was used to redistribute the temperature in a road surface and bridge-deck heating system in order to melt ice and snow during the winter (Balbay and Esen, 2010, Balbay and Esen, 2013; Esen and Yuksel, 2013). Similarly, a compact ground heat exchanger was developed for a solar-assisted ground source heat pump system (Esen et al., 2017). However, to more efficiently exploit geothermal resources, geothermal energy utilization and related technologies need to be further developed (Kazemi et al., 2019). China is rich in geothermal resources, some of which are buried in deep and ultra-deep layers under high temperatures. Therefore, the exploration and development of geothermal technologies have gradually shifted to environments with higher temperatures in deeper formations, which has led to the emergence of several exceedingly high-temperature deep wells (Song et al., 2017; Yang et al., 2019). Temperature and pressure during the drilling of deeper wells increase owing to the variation in the geothermal gradient and the influence of pressure gradients; thus, the drilling fluid quickly loses its original performance (Wang et al., 2019).
The conventional method to improve the performance of drilling fluids is to add an external treatment agent to increase their high-temperature resistance. Moreover, the treatment agent is an indispensable component of a drilling fluid system, and its temperature resistance is directly related to the high-temperature stability of such systems (Li et al., 2020; Geng et al., 2019). Thus, several countries have experienced a long-term and rapid development in the field of high-temperature drilling fluid treatment agents. In the 1960s, salt-tolerant, calcium-tolerant, high temperature-resistant (170°C) iron–chromium salts were successfully developed and used as viscosity reducers (Saric-Coric et al., 2003). In the 1970s, RESINEX was successfully developed, which withstands a temperature of 230°C and can be regarded as a sulfonated phenolic resin and lignite compound (Zhang et al., 2010). Currently, RESINEX is widely used in China. In addition, a variety of new treatment agents and drilling fluid systems have been studied globally in the 21st century to solve rheological alterations at high temperatures (Elkatatny, 2019; Huang et al., 2019; Chu et al., 2020).
To date, several scholars have focused on the research and development of high-temperature treatment agents. However, these studies only expanded the types of treatment agents and focused on improving the performance of the treatment agents. Moreover, these studies have not conducted in-depth research on slurry-making clay minerals. Most scholars across the world have studied and used bentonite and sepiolite, which exhibit beneficial effects and are inexpensive. However, the slurry-making performance of these minerals is poor in high-temperature environments, which makes it challenging to meet the needs of geothermal drilling (Dong et al., 2019; Hou et al., 2014; Al-Malki et al., 2016).
Previous studies have reported that clay minerals undergo dispersion, coalescence, and passivation under high-temperature conditions. Specifically, the high-temperature coalescence of clay particles plays a leading role at temperatures higher than 180 °C. In addition, high-temperature dehydration decreases the clay particle coalescence stability and results in varying degrees of coalescence, which increases the size of the clay particles in the drilling fluid (Luo et al., 2017). Moreover, a reduction in the specific surface area has a significant impact on the rheological characteristics of the drilling fluid. Thus, to develop a high-temperature resistant drilling fluid system that can meet the requirements of high-temperature geothermal drilling and exploration applications, the problems of high-temperature (>180°C) dispersion, coalescence, and passivation of slurry-making clay must first be addressed. To this end, this study investigated high temperature-resistant clay minerals, analyzed the slurry ability of these clay minerals, and explored their slurry-making and rheological properties under various high-temperature environments (180, 200, and 220 °C). The rectorite clay mineral was selected as the slurry-making additive for the drilling fluid system owing to its excellent high-temperature resistance. Subsequently, the rectorite was modified and analyzed for slurry yield, rheological behavior, and high-temperature stability. Finally, the deficiencies of the initial slurry were eliminated through modifications of the rectorite; suitable additives and formulations were determined to develop a high temperature-resistant drilling fluid system with excellent performance, simple system structure, and environmentally sustainable characteristics. Furthermore, comprehensive performance indicators, such as rheological behavior, filtration loss, pollution control, and inhibitory characteristics at high temperatures, were evaluated for this system.
Section snippets
Test materials
The primary clay minerals used in the experiment included sodium bentonite, montmorillonite, sepiolite, palygorskite, and rectorite with a purity of approximately 80% produced by Hubei Zhongxiang Mining Company. The organic modifiers used were cetyltrimethylammonium bromide (CTAB), and laponite (LP) synthesized by Guangzhou Haoxin Trading Co., Ltd. using a hydrothermal method. Moreover, Na2CO3 was added to improve the hydration and dispersion properties of the clays. The filtrate reducers
Optimization of slurry-making clay minerals
Geothermal drilling requires the drilling fluid to have a high density and flowability. However, the solid content along with the particle dispersibility of the drilling fluid increases with the dosage of the weighting materials. In addition, the rheological properties continue to deteriorate because of ineffective restrictions; therefore, the stabilization of the original rheological properties is necessary for the slurry-making clay. Moreover, the rheological properties and mud yield of the
Conclusions
- (1)
Rectorite exhibits good temperature resistance owing to its structural characteristics. The addition of LP increases the cohesion of rectorite particles; simultaneously, with the assistance of other treatment agents, the developed H-LT drilling fluid system exhibits an excellent rheological performance, low fluid loss volume, and good inhibitory performance at 220 °C.
- (2)
This paper presents a solution for critical problems in geothermal drilling and exploration pertaining to the high-temperature
Author Statement
Manuscript title: Rectorite drilling fluid: high-temperature resistance for geothermal applications
Sheng Wang has drafted this work and revised it critically for important intellectual content;
Zhijun Li has made substantial contributions to the conception, design, data analysis and interpretation of this work;
Qiang Chen has agreed to be accountable for all aspects of the work in ensuring that questions related to the accuracy or integrity of any part of the work are appropriately investigated
Declaration of Competing Interest
The authors of this research paper have no conflict of interest, financial or otherwise, and no conflict of interest with funding agencies.
Acknowledgements
This paper has been supported by National Natural Science of China (Grant No. 42072339, 41702388, U19A2097), the State Key Laboratory of Geohazard Prevention and Geoenvironment Protection (Grant No. SKLGP2019Z006) and Everest Technology Research Proposal of Chengdu University of Technology (Grant No. 80000-2020ZF11411).
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