Role of chemical cementation and hydration inhibition on wellbore stability in hydrate bearing sediment: Experimental and molecular dynamics simulation studies

Shao, Zihua; Wang, Jintang; Zhou, Mengmeng; Wang, Echuan; Lv, Kaihe; Wang, Zonglun; Huang, Xianbin; Ren, Wei; Lü, Cheng; Sun, Jinsheng

doi:10.1016/j.jngse.2022.104619

Cited by 4 publications

(4 citation statements)

References 43 publications

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“…They separately studied the interaction between three inhibitor molecules, namely, polyepoxypropane-diamine, polyethylene glycol, and polyepoxyethylene-dipropylene acid ester, with montmorillonite, providing molecular and atomic-level explanations for the interaction patterns between expansion inhibitors and clay minerals. Zihua et al (2022) [157] conducted a full-atom study on the mechanism of action of modified polyvinyl alcohol as a water-containing sediment wellbore stabilizer on rock matrix surfaces, explaining the adsorption of this wellbore stabilizer on the rock matrix surface and demonstrating that the entanglement of stabilizer molecule chains enhances the interaction force between upper and lower surfaces. Liao et al (2023) [158] revealed the inhibition mechanism of the natural gas hydrate inhibitor SYZ-2 they developed using MD: SYZ-2 inhibits hydrate nucleation by promoting the aggregation of methane molecules, reducing methane solubility.…”

Section: Drilling Fluid Additivesmentioning

confidence: 99%

The Application Potential of Artificial Intelligence and Numerical Simulation in the Research and Formulation Design of Drilling Fluid Gel Performance

Sheng,

He,

et al. 2024

Gels

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Drilling fluid is pivotal for efficient drilling. However, the gelation performance of drilling fluids is influenced by various complex factors, and traditional methods are inefficient and costly. Artificial intelligence and numerical simulation technologies have become transformative tools in various disciplines. This work reviews the application of four artificial intelligence techniques—expert systems, artificial neural networks (ANNs), support vector machines (SVMs), and genetic algorithms—and three numerical simulation techniques—computational fluid dynamics (CFD) simulations, molecular dynamics (MD) simulations, and Monte Carlo simulations—in drilling fluid design and performance optimization. It analyzes the current issues in these studies, pointing out that challenges in applying these two technologies to drilling fluid gelation performance research include difficulties in obtaining field data and overly idealized model assumptions. From the literature review, it can be estimated that 52.0% of the papers are related to ANNs. Leakage issues are the primary concern for practitioners studying drilling fluid gelation performance, accounting for over 17% of research in this area. Based on this, and in conjunction with the technical requirements of drilling fluids and the development needs of drilling intelligence theory, three development directions are proposed: (1) Emphasize feature engineering and data preprocessing to explore the application potential of interpretable artificial intelligence. (2) Establish channels for open access to data or large-scale oil and gas field databases. (3) Conduct in-depth numerical simulation research focusing on the microscopic details of the spatial network structure of drilling fluids, reducing or even eliminating data dependence.

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Section: Drilling Fluid Additivesmentioning

confidence: 99%

The Application Potential of Artificial Intelligence and Numerical Simulation in the Research and Formulation Design of Drilling Fluid Gel Performance

Sheng,

He,

et al. 2024

Gels

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“…Moreover, some scholars have pointed out that the decomposition of methane hydrate has a significant impact on reservoir strength [15], and the high ground stress difference of hydrate formation aggravates the risk of wellbore instability [16]. Some scholars have further explored the effect of methane hydrate inhibitors on inhibiting wellbore instability [17]. Existing studies generally believe that the decomposition of natural gas hydrate will increase the risk of wellbore instability, but the specific process of wellbore instability needs to be further studied.…”

Section: Introductionmentioning

confidence: 99%

Research on Wellbore Stability in Deepwater Hydrate-Bearing Formations during Drilling

Sun,

Wen,

Yang

2024

Energies

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Marine gas hydrate formations are characterized by considerable water depth, shallow subsea burial, loose strata, and low formation temperatures. Drilling in such formations is highly susceptible to hydrate dissociation, leading to gas invasion, wellbore instability, reservoir subsidence, and sand production, posing significant safety challenges. While previous studies have extensively explored multiphase flow dynamics between the formation and the wellbore during conventional oil and gas drilling, a clear understanding of wellbore stability under the unique conditions of gas hydrate formation drilling remains elusive. Considering the effect of gas hydrate decomposition on formation and reservoir frame deformation, a multi-field coupled mathematical model of seepage, heat transfer, phase transformation, and deformation of near-wellbore gas hydrate formation during drilling is established in this paper. Based on the well logging data of gas hydrate formation at SH2 station in the Shenhu Sea area, the finite element method is used to simulate the drilling conditions of 0.1 MPa differential pressure underbalance drilling with a borehole opening for 36 h. The study results demonstrate a significant tendency for wellbore instability during the drilling process in natural gas hydrate formations, largely due to the decomposition of hydrates. Failure along the minimum principal stress direction in the wellbore wall begins to manifest at around 24.55 h. This is accompanied by an increased displacement velocity of the wellbore wall towards the well axis in the maximum principal stress direction. By 28.07 h, plastic failure is observed around the entire circumference of the well, leading to wellbore collapse at 34.57 h. Throughout this process, the hydrate decomposition extends approximately 0.55 m, predominantly driven by temperature propagation. When hydrate decomposition is taken into account, the maximum equivalent plastic strain in the wellbore wall is found to increase by a factor of 2.1 compared to scenarios where it is not considered. These findings provide crucial insights for enhancing the safety of drilling operations in hydrate-bearing formations.

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“…For a long time, the mainstream view has been that the hydration reaction of clay minerals in shale is one of the most important factors affecting the shale strength. − Therefore, many scholars have studied the mechanisms of hydration and measures to reduce the shale hydration reaction. − On the one hand, inhibitory inorganic salts or organic salts represented by KCl are added to the drilling fluid in large quantities, effectively controlling the hydration reaction. On the other hand, different scales of micro–nano-scale particles are added to the drilling fluid in order to form a plugging layer in the shale and reduce the hydration reaction by preventing water entering the shale. , The above two methods have been considerably applied in drilling sites.…”

Section: Introductionmentioning

confidence: 99%

“…For a long time, the mainstream view has been that the hydration reaction of clay minerals in shale is one of the most important factors affecting the shale strength. 4 − 6 Therefore, many scholars have studied the mechanisms of hydration and measures to reduce the shale hydration reaction. 7 − 9 On the one hand, inhibitory inorganic salts or organic salts represented by KCl are added to the drilling fluid in large quantities, 10 effectively controlling the hydration reaction.…”

Section: Introductionmentioning

confidence: 99%

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

et al. 2022

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The problem of wellbore stability in hard brittle shale formations is an important research topic in the exploration and development of shale gas. To solve this problem, the adaptability of the plugging drilling fluid to wellbore stability in the hard brittle shale of the tertiary Dongying formation in Bohai Bay Basin, China, was investigated. The results show that the clay content of the hard brittle shale in the study block is as high as 39.2% on average, with great possibility for hydration. The pore structure in the shale is dominated by micron-scale fractures and pores. A dense structure was formed on the surface of the shale after being immersed in plugging drilling fluid, and the matrix permeability of the shale was reduced by 91.1% and the fracture permeability by 98.7%. The water content increment of the shale after immersion was merely 0.75%, which reduced the probability of hydration greatly. Compared with the field-inhibitive drilling fluid, the plugging drilling fluid improved the uniaxial compressive strength of shale by 28%, which is more conducive to maintaining the wellbore stability. The seepage stress aggravates the risk of wellbore instability, while the hydration stress does not, but both increase the risk of rock instability at positions away from the well wall. The plugging drilling fluid affects the seepage stress and hydration stress by reducing the shale permeability and water content. With the decrease of permeability and water content, the potential instability zone of a wellbore becomes smaller.

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Role of chemical cementation and hydration inhibition on wellbore stability in hydrate bearing sediment: Experimental and molecular dynamics simulation studies

Cited by 4 publications

References 43 publications

The Application Potential of Artificial Intelligence and Numerical Simulation in the Research and Formulation Design of Drilling Fluid Gel Performance

The Application Potential of Artificial Intelligence and Numerical Simulation in the Research and Formulation Design of Drilling Fluid Gel Performance

Research on Wellbore Stability in Deepwater Hydrate-Bearing Formations during Drilling

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

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