Experimental Study on the Adaptability of Plugging Drilling Fluids to Wellbore Stability in Hard Brittle Shale Formations

Zhang, Wen; Liu, Xiangjun; Liang, Lixi; Xiong, Jian

doi:10.1021/acsomega.2c04624

Cited by 3 publications

(1 citation statement)

References 31 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…In recent years, polyhydroxy-ammonium has received the extensive attention of researchers because of its more significant application effects in terms of inhibition, lubricity and stable rheology [10]. In addition, our research team has also conducted research in the field of drilling fluid treatment agents [11][12][13]. Therefore, we have proposed environmentally friendly alcohol amine inhibitors with multi-hydroxyl.…”

Section: Introductionmentioning

confidence: 99%

Preparation and Application of New Polyhydroxy Ammonium Shale Hydration Inhibitor

Chang,

Wang,

et al. 2023

Processes

View full text Add to dashboard Cite

Wellbore instability caused by the hydration of shale formations during drilling is a major problem in drilling engineering. In this paper, the shale inhibition performance of polyhydroxy-alkanolamine was evaluated using an anti-swelling test, linear swelling test, wash-durable test and montmorillonite hydration and dispersion experiment. Additionally, the shale inhibition mechanism of polyhydroxy-alkanolamine was studied via Fourier transform infrared spectroscopy (FTIR), particle size, zeta potential, thermogravimetric analysis (TGA) and scanning electron microscopy (SEM). The results show that the use of polyhydroxy-alkanolamine (EGP-2) could result in a relatively lower linear swelling rate of montmorillonite, and the linear swelling rate of 0.3% EGP-2 is 26.98%, which is stronger than that of 4% KCl. The anti-swelling rate of 0.3% EGP-2 is 43.54%, and the shrinkage–swelling rate of 0.3% EGP-2 is 34.62%. The study on the inhibition mechanism revealed that EGP-2 can permeate and adsorb on the surface of montmorillonite. The rolling recovery rate of easily hydrated shale was as high as 79.36%, which greatly reduces the dispersion ability of water to easily hydrated shale. The results of this study can be used to maintain the stability of a wellbore, which is conducive to related research.

show abstract

Section: Introductionmentioning

confidence: 99%

Preparation and Application of New Polyhydroxy Ammonium Shale Hydration Inhibitor

Chang,

Wang,

et al. 2023

Processes

View full text Add to dashboard Cite

show abstract

Analysis of changes in shale mechanical properties and fault instability activation caused by drilling fluid invasion into formations

Zhou,

Liu,

Liang

2024

J Petrol Explor Prod Technol

View full text Add to dashboard Cite

During the drilling process, the issue of drilling fluid loss can lead to changes in the mechanical properties of the formation, thereby altering the stress environment of nearby faults. In order to assess the risk of fault activation during drilling operations, the Ordos M area shale was selected as the research object. Mechanical experiments were conducted on rock samples immersed in water-based drilling fluid with a pressure differential of 2 MPa and a temperature of 50 °C. The changes in the mechanical properties of the shale before and after immersion in drilling fluid were determined. Based on the experimental results, combined with the spring combination model and fault activation theory, a quantitative evaluation of fault activation risk was conducted. The findings revealed that the shale in this region has a high clay content, demonstrating a certain level of water sensitivity. The presence of micro-pores and micro-fractures is well-developed, increasing the interaction probability between drilling fluids and clay minerals. After immersion in drilling fluid, there was a varied decline in all mechanical strengths of the shale. The elastic modulus is positively correlated with the shear strength and Coulomb stress of the fault plane. The Poisson’s ratio is positively correlated with the shear strength and negatively correlated with the Coulomb stress. The greater the internal friction and cohesion, the higher the shear strength of the fault plane, and the larger the friction coefficient, the smaller the Coulomb stress, resulting in a more stable fault.

show abstract

Investigation on the plugging mechanism of nanocomposite polyacrylate copolymers in water-based drilling fluids: Experiments and applications

Xie,

Xia,

Bai

et al. 2024

Geoenergy Science and Engineering

View full text Add to dashboard Cite

Experimental Study on the Adaptability of Plugging Drilling Fluids to Wellbore Stability in Hard Brittle Shale Formations

Cited by 3 publications

References 31 publications

Preparation and Application of New Polyhydroxy Ammonium Shale Hydration Inhibitor

Preparation and Application of New Polyhydroxy Ammonium Shale Hydration Inhibitor

Analysis of changes in shale mechanical properties and fault instability activation caused by drilling fluid invasion into formations

Investigation on the plugging mechanism of nanocomposite polyacrylate copolymers in water-based drilling fluids: Experiments and applications

Contact Info

Product

Resources

About