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Journal articles on the topic 'Wellbore stability'

Author: Grafiati

Published: 4 June 2021

Last updated: 11 June 2025

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1

Akl, Sherif A. Y., and Andrew J. Whittle. "Stability analyses for deviated wellbores in unconsolidated cross-anisotropic formations." Canadian Geotechnical Journal 53, no. 9 (2016): 1450–59. http://dx.doi.org/10.1139/cgj-2015-0456.

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Production of oil from shallow reservoirs typically involves drilling highly deviated wells through unconsolidated (or poorly lithified) rocks or clays. This paper describes numerical analyses of the deformations and stability of deviated wellbores within a K0-consolidated clay. The analyses consider planar deformations in the plane orthogonal to the wellbore using a quasi three-dimensional (3D) finite element model that represents coupled flow and deformations within the soil mass. Cross-anisotropic mechanical properties of the clay are described by a generalized effective stress model, MIT-E3, with parameters previously calibrated from laboratory thick-walled cylinder tests. The analyses compute the relationship between the drilling mud pressure and wellbore stability associated with either the onset of localized failure mechanisms or large plastic deformations around the cavity. The results show that short-term, undrained stability requires mud pressures in excess of the in situ formation pore pressures for more highly deviated wellbores at inclinations greater than 45°. The analyses examine the mechanisms for further destabilization, due to consolidation within the formation, and how they are affected by drainage conditions at the wellbore wall. The results provide qualitative information for the design and control of drilling operations for deviated wellbores in unconsolidated formations.

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2

Kremieniewski, Marcin. "Ultra-Lightweight Cement Slurry to Seal Wellbore of Poor Wellbore Stability." Energies 13, no. 12 (2020): 3124. http://dx.doi.org/10.3390/en13123124.

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The article presents the recipe for ultra-lightweight cement slurry for wellbore sealing. In ordinary lightweight cement slurries, the addition of microspheres and a large amount of water are used to maintain rheological parameters. This is a problem because the light particles of microspheres segregate. The cement sheath from such a cement slurry has an anisotropic microstructure and does not stabilize the casing column. In the new ultra-light cement slurry, 60% aluminosilicate microspheres and a large amount of water were used. The ultra-light weight slurry has a density below 1.2 g/cm3. This cement slurry does not segregates and in the sedimentation stability test has the same density at all measuring points. The cement slurry, despite the larger amount of water, has the same filtration as the control sample. The technological parameters of the slurry are adapted to the borehole conditions. Cement slurry is a ready-made application to seal a borehole with poor wellbore stability under conditions of 40 °C and 10 MPa pressure. The cement sheath structure in the wellbore after binding is homogeneous. The use of such slurry allows to reduce the risk of wall damage in wellbores of poor stability.

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3

Shi, Xiang-Chao, Xu Yang, Ying-Feng Meng, and Gao Li. "Wellbore stability analysis in chemically active shale formations." Thermal Science 20, suppl. 3 (2016): 911–17. http://dx.doi.org/10.2298/tsci16s3911s.

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Maintaining wellbore stability involves significant challenges when drilling in low-permeability reactive shale formations. In the present study, a non-linear thermo-chemo-poroelastic model is provided to investigate the effect of chemical, thermal, and hydraulic gradients on pore pressure and stress distributions near the wellbores. The analysis indicates that when the solute concentration of the drilling mud is higher than that of the formation fluid, the pore pressure and the effective radial and tangential stresses decrease, and v. v. Cooling of the lower salinity formation decreases the pore pressure, radial and tangential stresses. Hole enlargement is the combined effect of shear and tensile failure when drilling in high-temperature shale formations. The shear and tensile damage indexes reveal that hole enlargement occurs in the vicinity of the wellbore at an early stage of drilling. This study also demonstrates that shale wellbore stability exhibits a time-delay effect due to changes in the pore pressure and stress. The delay time computed with consideration of the strength degradation is far less than that without strength degradation.

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4

Mehrabian, Amin. "The Stability of Inclined and Fractured Wellbores." SPE Journal 21, no. 05 (2016): 1518–36. http://dx.doi.org/10.2118/180910-pa.

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Summary The theory of linear-elastic fracture mechanics is used to develop an analytical solution for a wellbore in an isotropic elastic medium when drilled inclined to a general state of 3D far-field stress, and attached to which are an arbitrary number of N straight and axially aligned fractures. Axial alignment refers to the special case where the borehole axis is the existing common interface of all planes defined by the fracture faces. The solution uses a familiar load decomposition and coordinate-transform scheme. Within the fracture-mechanics context of the analysis, this scheme translates into a set of three fundamental subproblems comprising a uniaxial stress problem, together with an in-plane mixed mode (Modes I and II), and a Mode III antiplane-crack/cavity-interaction problem. The overall solution is obtained by superposing the solutions to these subproblems. A numerical example is presented to demonstrate its usefulness in the stability analysis of inclined and fractured wellbores. Attention has been directed toward the underlying significance that the results would bring in fundamental understanding of lost-circulation events. For this purpose, the criteria for a possible extended margin of the mud weight that secures stable states of a fractured wellbore are recognized and quantified. These criteria include the wellbore-wall refracturing and the existing fractures propagation.

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5

Pla´cido, Joa˜o Carlos R., He´lio M. R. Santos, and Yadira Diaz Galeano. "Drillstring Vibration and Wellbore Instability." Journal of Energy Resources Technology 124, no. 4 (2002): 217–22. http://dx.doi.org/10.1115/1.1501302.

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Wellbore instability can be attributed to several causes. The ones thought to be most important include: chemical interaction with the drilling fluid, high tectonic stresses, and insufficient mud weight. Drillstring vibration, although not traditionally addressed as a potential cause, might influence the stability of wellbores drilled in specific formations. Evidence of the strong correlation between severe vibration and wellbore instability has been reported in the literature. However, a more thorough understanding of the phenomenon is still lacking. This paper describes a study that has been developed by PETROBRAS focusing on how drillstring vibration impacts wellbore instability. Vibration has been monitored in some wells, and events related to borehole enlargement were observed. Four field cases are presented showing a strong correlation between high vibration level and wellbore enlargement in different lithologies. Other sources of wellbore enlargement have also been identified, and they can be clearly separated from vibration.

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6

Kwakwa, Kwabena. "Overview: Wellbore Stability (October 2002)." Journal of Petroleum Technology 54, no. 10 (2002): 56. http://dx.doi.org/10.2118/1002-0056-jpt.

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7

Bybee, Karen. "Time-Dependent Wellbore- Stability Predictions." Journal of Petroleum Technology 53, no. 02 (2001): 29–30. http://dx.doi.org/10.2118/0201-0029-jpt.

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8

Kwakwa, Kwabena. "Overview: Wellbore Stability (May 2001)." Journal of Petroleum Technology 53, no. 05 (2001): 54. http://dx.doi.org/10.2118/0501-0054-jpt.

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9

Chen, Guizhong, and Russell T. Ewy. "Thermoporoelastic Effect on Wellbore Stability." SPE Journal 10, no. 02 (2005): 121–29. http://dx.doi.org/10.2118/89039-pa.

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10

Do, Khanh Quang, Nam Nguyen Hai Le, Quang Trong Hoang, and Huy Xuan Nguyen. "Wellbore stability analysis based on the stress model around boreholes." Science and Technology Development Journal - Natural Sciences 1, T5 (2018): 290–301. http://dx.doi.org/10.32508/stdjns.v1it5.562.

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Wellbore stability analysis plays an important role in the oil and gas drilling. Instability problems during the drilling phase are often the results of a combination of both mechanical and chemical effects. This study aims to assess the mechanical wellbore stability based on the stress model around boreholes. The development of the stress model around boreholes, which is associated with the in-situ stresses, rock properties as well as the wellbore pressure and configuration, are presented. It could visualize the stress distribution around an arbitratily orientated wellbore. Next, lower hemisphere diagrams are presented to demonstrate the wellbore pressure required to initiate borehole tensile and compressive failures. A program for the risk analysis of wellbore (RAoWB) is designed and developed by the Matlab programming language to describe and analyse the risk diagrams of the drilling induced tensile fractures (DITFs) and breakouts (BOs). They help to choice the optimum wellbore trajectories for well planning, as well as to predict the wellbore instabilities caused by inappropriate wellbore pressures.

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11

Huan, Xiaolin, Gao Xu, Yi Zhang, Feng Sun, and Shifeng Xue. "Study on Thermo-Hydro-Mechanical Coupling and the Stability of a Geothermal Wellbore Structure." Energies 14, no. 3 (2021): 649. http://dx.doi.org/10.3390/en14030649.

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For processes such as water injection in deep geothermal production, heat transfer and fluid flow are coupled and affect one another, which leads to numerous challenges in wellbore structure safety. Due to complicated wellbore structures, consisting of casing, cement sheaths, and formations under high temperature, pressure, and in situ stress, the effects of thermo-hydro-mechanical (THM) coupling are crucial for the instability control of geothermal wellbores. A THM-coupled model was developed to describe the thermal, fluid, and mechanical behavior of the casing, cement sheath, and geological environment around the geothermal wellbore. The results show that a significant disturbance of effective stress occurred mainly due to the excess pore pressure and temperature changes during cold water injection. The effective stress gradually propagated to the far-field and disrupted the integrity of the wellbore structure. A serious thermal stress concentration occurred at the junction of the cased-hole and open-hole section. When the temperature difference between the injected water and the formation was up to 160 °C, the maximum hoop tensile stress in the granite formation reached up to 43.7 MPa, as high as twice the tensile strength, which may increase the risk of collapse or rupture of the wellbore structure. The tensile radial stress, with a maximum of 31.9 MPa concentrated at the interface between the casing and cement sheath, can cause the debonding of the cementing sheath. This study provides a reference for both the prediction of THM responses and the design of drilling fluid density in geothermal development.

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12

Zhang, Feifei, Yongfeng Kang, Zhaoyang Wang, Stefan Miska, Mengjiao Yu, and Zahra Zamanipour. "Transient Coupling of Swab/Surge Pressure and In-Situ Stress for Wellbore-Stability Evaluation During Tripping." SPE Journal 23, no. 04 (2018): 1019–38. http://dx.doi.org/10.2118/180307-pa.

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Summary This paper identifies wellbore-stability concerns caused by transient swab/surge pressures during deepwater-drilling tripping and reaming operations. Wellbore-stability analysis that couples transient swab/surge wellbore-pressure oscillations and in-situ-stress field oscillations in the near-wellbore (NWB) zone in deepwater drilling is presented. A transient swab/surge model is developed by considering drillstring components, wellbore structure, formation elasticity, pipe elasticity, fluid compressibility, fluid rheology, and the flow between wellbore and formation. Real-time pressure oscillations during tripping/reaming are obtained. On the basis of geomechanical principles, in-situ stress around the wellbore is calculated by coupling transient wellbore pressure with swab/surge pressure, pore pressure, and original formation-stress status to perform wellbore-stability analysis. By applying the breakout failure and wellbore-fracture failure in the analysis, a work flow is proposed to obtain the safe-operating window for tripping and reaming processes. On the basis of this study, it is determined that the safe drilling-operation window for wellbore stability consists of more than just fluid density. The oscillation magnitude of transient wellbore pressure can be larger than the frictional pressure loss during the normal-circulation process. With the effect of swab/surge pressure, the safe-operating window can become narrower than expected. The induced pore pressure decreases monotonically as the radial distance increases, and it is limited only to the NWB region and dissipates within one to two hole diameters away from the wellbore. This study provides insight into the integration of wellbore-stability analysis and transient swab/surge-pressure analysis, which is discussed rarely in the literature. It indicates that tripping-induced transient-stress and pore-pressure changes can place important impacts on the effective-stress clouds for the NWB region, which affect the wellbore-stability status significantly.

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13

Jia, Shanpo, Caoxuan Wen, Fucheng Deng, Chuanliang Yan, and Zhiqiang Xiao. "Coupled THM Modelling of Wellbore Stability with Drilling Unloading, Fluid Flow, and Thermal Effects Considered." Mathematical Problems in Engineering 2019 (April 9, 2019): 1–20. http://dx.doi.org/10.1155/2019/5481098.

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Both overbalanced drilling and underbalanced drilling will lead to the change of pore pressure around wellbore. Existing research is generally based on hydraulic-mechanical (HM) coupling and assumes that pore pressure near the wellbore is initial formation pressure, which has great limitations. According to the coupled theory of mixtures for rock medium, a coupled thermal-hydraulic-mechanical (THM) model is proposed and derived, which is coded with MATLAB language and ABAQUS software as the solver. Then the wellbore stability is simulated with the proposed model by considering the drilling unloading, fluid flow, and thermal effects between the borehole and the formation. The effect of field coupling on pore pressure, stress redistribution, and temperature around a wellbore has been analyzed in detail. Through the study of wellbore stability in different conditions, it is found that (1) for overbalanced drilling, borehole with impermeable wall is more stable than that of ones with permeable wall and its stability can be improved by reducing the permeable ability of the wellbore wall; (2) for underbalanced drilling, the stability condition of permeable wellbore is much higher than that of impermeable wellbore; (3) the temperature has important influence on wellbore stability due to the variation of pore pressure and thermal stress; the wellbore stability can be improved with cooling drilling fluid for deep well. The present method can provide references for coupled thermal-hydraulic-mechanical-chemical (THMC) process analysis for wellbore.

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14

Liu, Wei, Hai Lin, Hailong Liu, Chao Luo, Guiping Wang, and Jingen Deng. "Numerical Investigation of Wellbore Stability in Deepwater Shallow Sediments." Geofluids 2021 (March 13, 2021): 1–14. http://dx.doi.org/10.1155/2021/5582605.

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An elaborate poro-elastoplastic numerical model has been developed in this paper to explore the stability characteristics of wellbore in shallow sediments of deepwater oil/gas wells. The combined Drucker-Prager/cap plasticity model is employed to characterize the mechanical behavior of the weakly consolidated or unconsolidated shallow sediments, by which both plastic compaction deformation and plastic shear deformation can be considered. Possible penetration of drilling fluid into the formation and its coupling to deformation have also been accounted for in the model. Using this model, deformation, stress evolution, and failure characteristics of the formation around the wellbore are analyzed in detail. Results presented in this paper demonstrate the necessity of considering the plastic compaction capability of the formation during the wellbore stability analysis of shallow sediments in deepwater. For mud pressures lower than the in situ horizontal stress, excessive wellbore shrinkage may occur if the mud pressure is too low, which, however, can be effectively mitigated through properly increasing the mud pressure even fluid penetration into the near-wellbore region may occur. It is also evidenced that, if penetration of drilling fluid into the formation is prevented, fracturing of the wellbore will not occur even the mud pressure is very high. Instead, the wellbore will expand substantially due to plastic compaction, and the deformed wellbore radius could be several times larger than the original value. However, if drilling fluid can penetrate into the formation, high pore pressure will develop within the near-wellbore region, resulting in tensile hoop stress at the wellbore and thus fracturing of the wellbore along the radial direction. The numerical results and implications in this paper are anticipated to be beneficial for the drilling operation in the shallow portion of deepwater oil/gas wells.

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15

Dosunmu, Adewale, Roland I. Nwonodi, and Evelyn Ekeinde. "Analysis of the Collapse Gradient of Deep Water Horizontal Wellbore and the Effects of Mud Chemical Activity and Variation in Water Depth." Studia Geotechnica et Mechanica 42, no. 3 (2020): 232–41. http://dx.doi.org/10.2478/sgem-2019-0040.

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AbstractWellbore collapse is an instability-event that occurs at low mud density and leads to unfavorable economic project, reaching billions of US dollars. Thus, it is important to accurately determine its value, especially in deepwater horizontal wellbores. The main reasons for nontrivial problems with such wellbores are evident: the shale encountered are anisotropic in nature and possess planes of weakness; they react with water-based mud, generate osmotic stresses, swell, and fall unto the wellbore bottom, thereby increasing the non-productive time. To this end, salts are added to reduce the collapse tendency, but it is not currently known what amount of salt addition maintains stability, and does not lead to wellbore fracture; in deepwater, the current trend in global warming means there is a future concern to the industry. As the climate temperature increases, more ice melts from the polar region, the seawater expands and the sea level rises. How to incorporate the corresponding effect on collapse gradient is scarcely known. This study captures the major concerns stated above into wellbore stability analysis. Following the classical approach for geomechanical analysis, Mogi-Coulomb criterion was combined with a constitutive stress equation comprising contributions from mechanical and osmotic potentials of mud and shale. A sophisticated industry model was used to consider the deepwater effect. The results show significant reduction in collapse gradient as the water depth increases, also, larger difference between the mud and shale chemical activities represents higher complexities in the wellbore. In addition, the reduction in the chemical activities of mud limited to 37.5% of the initial value can be practically safe.

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16

Mohammed, Rehan Ali, Seyedalireza Khatibi, Mehdi Ostadhassan, Azadeh Aghajanpour, and Alexeyev Alan. "Advanced Geomechanical Earth Model for Predicting Wellbore Stability and Fracking Potential." International Journal of Chemical Engineering and Applications 9, no. 2 (2018): 38–45. http://dx.doi.org/10.18178/ijcea.2018.9.2.696.

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17

Zhang, Xia, Xu, and Han. "Stability Analysis of Near-Wellbore Reservoirs Considering the Damage of Hydrate-Bearing Sediments." Journal of Marine Science and Engineering 7, no. 4 (2019): 102. http://dx.doi.org/10.3390/jmse7040102.

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The stability of hydrate-bearing near-wellbore reservoirs is one of the key issues in gas hydrate exploitation. In most previous investigations, the damage evolution process of the sediment structure and its effect on near-wellbore reservoir stability have been neglected. Therefore, the damage variable is introduced into a multi-field coupled model based on continuous damage theory and multi-field coupling theory. A thermo-hydro-mechanical-chemical (THMC) multi-field coupling mathematical model considering damage of hydrate-bearing sediments is established. The effects of damage of hydrate-bearing sediments on the thermal field, seepage field, and mechanical field are considered. Finally, the distributions of hydrate saturation, pore pressure, damage variable, and effective stress of a near-wellbore reservoir in gas hydrate exploitation by depressurization are calculated, and the stability of a hydrate-bearing near-wellbore reservoir is analyzed using the model. Through calculation and analysis, it is found that structural damage of hydrate-bearing sediments has an adverse effect on the stability of hydrate-bearing near-wellbore reservoirs. The closer to the wellbore, the worse the reservoir stability, and the near-wellbore reservoir stability is the worst in the direction of minimum horizontal ground stress.

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18

Al-Khayari, Mahmood R., Adel M. Al-Ajmi, and Yahya Al-Wahaibi. "Probabilistic Approach in Wellbore Stability Analysis during Drilling." Journal of Petroleum Engineering 2016 (December 26, 2016): 1–13. http://dx.doi.org/10.1155/2016/3472158.

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In oil industry, wellbore instability is the most costly problem that a well drilling operation may encounter. One reason for wellbore failure can be related to ignoring rock mechanics effects. A solution to overcome this problem is to adopt in situ stresses in conjunction with a failure criterion to end up with a deterministic model that calculates collapse pressure. However, the uncertainty in input parameters can make this model misleading and useless. In this paper, a new probabilistic wellbore stability model is presented to predict the critical drilling fluid pressure before the onset of a wellbore collapse. The model runs Monte Carlo simulation to capture the effects of uncertainty in in situ stresses, drilling trajectories, and rock properties. The developed model was applied to different in situ stress regimes: normal faulting, strike slip, and reverse faulting. Sensitivity analysis was applied to all carried out simulations and found that well trajectories have the biggest impact factor in wellbore instability followed by rock properties. The developed model improves risk management of wellbore stability. It helps petroleum engineers and field planners to make right decisions during drilling and fields’ development.

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19

Abdel Azim, Reda. "Simulation of Wellbore Stability during Underbalanced Drilling Operation." Journal of Applied Mathematics 2017 (2017): 1–12. http://dx.doi.org/10.1155/2017/2412397.

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The wellbore stability analysis during underbalance drilling operation leads to avoiding risky problems. These problems include (1) rock failure due to stresses changes (concentration) as a result of losing the original support of removed rocks and (2) wellbore collapse due to lack of support of hydrostatic fluid column. Therefore, this paper presents an approach to simulate the wellbore stability by incorporating finite element modelling and thermoporoelastic environment to predict the instability conditions. Analytical solutions for stress distribution for isotropic and anisotropic rocks are presented to validate the presented model. Moreover, distribution of time dependent shear stresses around the wellbore is presented to be compared with rock shear strength to select appropriate weight of mud for safe underbalance drilling.

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20

Martemyanov, A., S. Lukin, Yu Ovcharenko, et al. "Analytic Modelling for Wellbore Stability Analysis." Procedia Structural Integrity 6 (2017): 292–300. http://dx.doi.org/10.1016/j.prostr.2017.11.045.

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21

Chen, X., C. P. Tan, and C. M. Haberfield. "Guidelines for efficient wellbore stability analysis." International Journal of Rock Mechanics and Mining Sciences 34, no. 3-4 (1997): 50.e1–50.e14. http://dx.doi.org/10.1016/s1365-1609(97)00266-9.

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22

Stavropoulou, M., P. Papanastasiou, and I. Vardoulakis. "Coupled wellbore erosion and stability analysis." International Journal for Numerical and Analytical Methods in Geomechanics 22, no. 9 (1998): 749–69. http://dx.doi.org/10.1002/(sici)1096-9853(199809)22:9<749::aid-nag944>3.0.co;2-k.

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23

Cao, Yuan, and Jingen Deng . "Wellbore Stability Research of Heterogeneous Formation." Journal of Applied Sciences 14, no. 1 (2013): 33–39. http://dx.doi.org/10.3923/jas.2014.33.39.

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24

Wang, Xiao Zeng, Zhan Qu, and Yi Hua Dou. "Stress Distribution of Wellbore under Non-Uniform In Situ Stress." Applied Mechanics and Materials 633-634 (September 2014): 1311–14. http://dx.doi.org/10.4028/www.scientific.net/amm.633-634.1311.

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The distribution of the non-uniform in situ stress around wellbore will impair the stability of the rock of wellbore wall. Drilling the underbalanced wells and depleted formations, the instability of the wellbore can result in the drilling failure. Mechanics model of the wellbore wall rock is developed. According to the relationship between the stress function and components of stresses, the superposition principle is adopted to develop the formulas of the radial, hoop, and shear stresses of the wellbore wall under the non-uniform in situ stress. The formula of the mud density which do not crash the rock of wellbore wall is derived. The error of the mud density between fitting formula developed in the paper and theoretical method is less than 2.5%. The mud density that ensure the stability of wellbore is determined.

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25

Sang, Jian Bing, Su Fang Xing, Chen Hua Lu, Wen Jia Wang, and Bo Liu. "Elasto-Plastic Analysis on Wellbore Stability under the Condition of Permeation." Advanced Materials Research 156-157 (October 2010): 1292–96. http://dx.doi.org/10.4028/www.scientific.net/amr.156-157.1292.

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Maintaining the wellbore stability is a key factor for oil and gas drilling operations. In this paper, sock is regarded porous medium. Crevice pressure, effect of permeation and SD effect are considered. The elastic and plastic stresses around the wellbore sock were analysed according to MVM failure criterion. Distribution of stress and displacement was obtained, which can provide theory reference for the wellbore stability.

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26

Batalha, Nathalia A., Omar Y. Duran, Philippe R. B. Devloo, and Luiz C. M. Vieira. "Stability analysis and uncertainty modeling of vertical and inclined wellbore drilling through heterogeneous field." Oil & Gas Science and Technology – Revue d’IFP Energies nouvelles 75 (2020): 14. http://dx.doi.org/10.2516/ogst/2020003.

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A stochastic two-dimensional geomechanical model developed by the authors and presented herein is used to analyze wellbore stability in heterogeneous formations. It consists of a finite element model and assumes linear elastic and isotropic material behavior under the plane strain state. The model simulates the stress state around vertical and inclined wellbore when a formation is submitted to internal drilling fluid pressure. This new state of stress may lead to rock failure, which is analyzed through a failure criteria. Since the exact variation of formation’s mechanical properties is not known, a spatially correlated field is used to evaluate the variability of a rock mechanical material property. The correlation between each pair of finite elements is determined by a covariance function. A two-dimensional spatially correlated field is used to verify the correlation between the elements of a vertical wellbore. A different approach, however, is necessary to model inclined wellbores. Once the direction and inclination of a wellbore are defined, a three-dimensional spatially correlated field becomes necessary to best simulate the formation field. Simulations using the stochastic model proposed herein and considering constant elastic modulus have been compared. It is observed that when considering the same elastic modulus along the field, the area of the plastic zone is symmetric at the borehole wall; when using the stochastic model, however, the plastic zone area surrounding the well is not symmetric; thus, the most vulnerable plastic zone may lead to premature failure. Stochastic simulations have been carried out with different heterogeneous fields for vertical and inclined wells, and distributions of the total plastic zone areas are obtained for each case. Based on the stochastic field probabilistic analysis, a distribution function is presented, which aims to define a stability framework analysis to best assist a decision making process in determining if a mud pressure is operationally acceptable or not.

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27

Denney, Dennis. "Wellbore-Stability Assessment for Self-Killing Blowouts." Journal of Petroleum Technology 65, no. 01 (2013): 105–10. http://dx.doi.org/10.2118/0113-0105-jpt.

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28

Carpenter, Chris. "Uncertainty Evaluation of Wellbore-Stability-Model Predictions." Journal of Petroleum Technology 66, no. 01 (2014): 91–92. http://dx.doi.org/10.2118/0114-0091-jpt.

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29

Santarelli, F. J., S. Zaho, G. Burrafato, F. Zausa, and D. Giacca. "Wellbore Stability Analysis Made Easy and Practical." SPE Drilling & Completion 12, no. 04 (1997): 212–18. http://dx.doi.org/10.2118/35105-pa.

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30

Bybee, Karen. "Wellbore Stability in a Weak-Carbonate Reservoir." Journal of Petroleum Technology 51, no. 10 (1999): 56. http://dx.doi.org/10.2118/1099-0056-jpt.

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31

Udegbunam, John Emeka, Bernt Sigve Aadnøy, and Kjell Kåre Fjelde. "Uncertainty evaluation of wellbore stability model predictions." Journal of Petroleum Science and Engineering 124 (December 2014): 254–63. http://dx.doi.org/10.1016/j.petrol.2014.09.033.

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32

Zhang, Jincai, Mao Bai, and J. C. Roegiers. "Dual-porosity poroelastic analyses of wellbore stability." International Journal of Rock Mechanics and Mining Sciences 40, no. 4 (2003): 473–83. http://dx.doi.org/10.1016/s1365-1609(03)00019-4.

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33

Aregbe, Azeez G. "Wellbore Stability Problems in Deepwater Gas Wells." World Journal of Engineering and Technology 05, no. 04 (2017): 626–47. http://dx.doi.org/10.4236/wjet.2017.54053.

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34

Zhao, Haifeng, Mian Chen, Yawei Li, and Wei Zhang. "Discrete element model for coal wellbore stability." International Journal of Rock Mechanics and Mining Sciences 54 (September 2012): 43–46. http://dx.doi.org/10.1016/j.ijrmms.2012.05.006.

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35

Meng, Meng, Zahra Zamanipour, Stefan Miska, Mengjiao Yu, and E. M. Ozbayoglu. "Dynamic Wellbore Stability Analysis Under Tripping Operations." Rock Mechanics and Rock Engineering 52, no. 9 (2019): 3063–83. http://dx.doi.org/10.1007/s00603-019-01745-4.

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36

Hao, Yang. "Effect of Stratum Properties on Wellbore Stability." Chemistry and Technology of Fuels and Oils 51, no. 5 (2015): 556–63. http://dx.doi.org/10.1007/s10553-015-0639-0.

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37

Mehrabian, Amin, and Younane Abousleiman. "Wellbore Geomechanics of Extended Drilling Margin and Engineered Lost-Circulation Solutions." SPE Journal 22, no. 04 (2017): 1178–88. http://dx.doi.org/10.2118/185945-pa.

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Summary Wellbore tensile failure is a known consequence of drilling with excessive mud weight, which can cause costly events of lost circulation. Despite the successful use of lost-circulation materials (LCMs) in treating lost-circulation events of the drilling operations, extensions of wellbore-stability models to the case of a fractured and LCM-treated wellbore have not been published. This paper presents an extension of the conventional wellbore-stability analysis to such circumstances. The proposed wellbore geomechanics solution revisits the criteria for breakdown of a fractured wellbore to identify an extended margin for the equivalent circulation density (ECD) of drilling. An analytical approach is taken to solve for the related multiscale and nonlinear problem of the three-way mechanical interaction between the wellbore, fracture wings, and LCM aggregate. The criteria for unstable propagation of existing near-wellbore fractures, together with those for initiating secondary fractures from the wellbore, are obtained. Results suggest that, in many circumstances, the occurrence of both incidents can be prevented, if the LCM blend is properly engineered to recover certain depositional and mechanical properties at downhole conditions. Under such optimal design conditions, the maximum ECD to which the breakdown limit of a permeable formation could be enhanced is predicted.

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Meng, Meng, Stefan Z. Miska, Mengjiao Yu, and Evren M. Ozbayoglu. "Fully Coupled Modeling of Dynamic Loading of the Wellbore." SPE Journal 25, no. 03 (2019): 1462–88. http://dx.doi.org/10.2118/198914-pa.

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Summary Loadings acting on a wellbore are more realistically regarded as dynamic rather than static, and the wellbore response under dynamic loading can be different from that under static loading. Under dynamic loading, the inertia term should be considered and the changing rate of loading could induce a change in the mechanical properties of the wellbore, which might compromise wellbore stability and integrity. In this paper, a fully coupled poroelastodynamic model is proposed to study wellbore behavior. This model not only considers fully coupled deformation/diffusion effects, but also includes both solid and fluid inertia terms. The implicit finite-difference method was applied to solve the governing equations, which allows this model to handle all kinds of dynamic loading conditions. After modifying the existing code only slightly, our numerical solution can neglect inertia terms. The numerical results were validated by comparing them to the analytical solution with a simulated sinusoidal boundary condition. To understand this model better, a sensitivity analysis was performed, and the influence of inertia terms was investigated. After that, the model was applied to analyze wellbore stability under tripping operations. The results show that the inertial effect is insignificant for tripping and a fully coupled, quasistatic model is recommended for wellbore stability under tripping operations. The fully coupled poroelastodynamic model should be used for rapid dynamic loading conditions, such as earthquakes and perforations.

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Addis, M. A., and R. G. Jeffrey. "SUMHOLE DRILLING: WELLBORE STABILITY CONSIDERATIONS BASED UPON FIELD AND LABORATORY DATA." APPEA Journal 36, no. 1 (1996): 544. http://dx.doi.org/10.1071/aj95032.

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Slimhole drilling is becoming an attractive option as it provides significant cost savings in the petroleum industry. Furthermore, many of the technical obstacles in adapting slimhole drilling for the petroleum industry have been addressed, such as rig modifications, small volume kick detection, drilling fluid design, etc. However, wellbore stability in slimholes is largely taken for granted, when it could potentially increase costs dramatically. In this paper, a review of the available information on the effects of hole size on hole stability is presented. Wellbore stability in holes of different diameters is discussed qualitatively based on published laboratory data and unpublished field data. The quantitative assessment of wellbore instability in slimholes is addressed using observations of instability in a well in which the far field stresses were measured.The field data presented here suggest that slimhole wells are not more stable than conventional wells. The slimhole drilled in NSW shows that even using the most conservative prediction model, wellbore instability would not be predicted—instability was however, observed.

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Barton, C. A., D. A. Castillo, D. Moos, P. Peska, and M. D. Zoback. "CHARACTERISING THE FULL STRESS TENSOR BASED ON OBSERVATIONS OF DRILLING-INDUCED WELLBORE FAILURES IN VERTICAL AND INCLINED BOREHOLES LEADING TO IMPROVED WELLBORE STABILITY AND PERMEABILITY PREDICTION." APPEA Journal 38, no. 1 (1998): 466. http://dx.doi.org/10.1071/aj97023.

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To minimise wellbore failures in unstable environments, knowledge of the complete stress tensor is crucial to designing optimally-stable borehole trajectories, selecting suitable mud weights, and determining appropriate casing points. Understanding how the in situ stress field interacts with the drilling and production of a well enables one to design for maximum stability and to facilitate intersecting the greatest population of hydraulically-conductive fractures for efficient production. Knowledge of the in situ stress field is also important to reduce uncertainties in sand production prediction to allow more aggressive completion designs and production schedules.A new interactive software system, Stress and Failure of Inclined Boreholes (SFIB) (Peska and Zoback, 1995a) is used to demonstrate how observations of drilling-induced compressive and tensile wellbore failures from acoustic and electrical images in vertical and inclined boreholes can be integrated with routinely-collected drilling data (leak-off and drill stem tests) to construct a well-constrained stress tensor. These techniques can also exploit wellbore image data to constrain in situ rock strength in vertical and inclined wells. This paper illustrates how to apply this knowledge to limit wellbore instability, design optimally stable wellbores, develop constraints that help mitigate problems associated with sand production, and optimise productivity of fractured reservoirs.In addition to mapping drilling-induced wellbore features, image data can also be used to determine the distribution, orientation, and apparent aperture of natural fractures and fault systems. With knowledge of the orientations and magnitudes of the in situ stresses it is possible to identify the subset of fractures that are likely to be hydraulically conductive.Examples of recent applications in the North Sea, Gulf of Mexico, California, and Puerto Rico illustrating how this integrated approach can be used in a variety of tectonic settings.

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Kim, Jung-Tae, Ah-Ram Kim, Gye-Chun Cho, Chul-Whan Kang, and Joo Yong Lee. "The Effects of Coupling Stiffness and Slippage of Interface Between the Wellbore and Unconsolidated Sediment on the Stability Analysis of the Wellbore Under Gas Hydrate Production." Energies 12, no. 21 (2019): 4177. http://dx.doi.org/10.3390/en12214177.

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Gas hydrates have great potential as future energy resources. Several productivity and stability analyses have been conducted for the Ulleung Basin, and the depressurization method is being considered for production. Under depressurization, ground settlement occurs near the wellbore and axial stress develops. For a safe production test, it is essential to perform a stability analysis for the wellbore and hydrate-bearing sediments. In this study, the development of axial stress on the wellbore was investigated considering the coupling stiffness of the interface between the wellbore and sediment. A coupling stiffness model, which can consider both confining stress and slippage phenomena, was suggested and applied in a numerical simulation. Parametric analyses were conducted to investigate the effects of coupling stiffness and slippage on axial stress development. The results show that shear coupling stiffness has a significant effect on wellbore stability, while normal coupling stiffness has a minor effect. In addition, the maximum axial stress of the well bore has an upper limit depending on the magnitude of the confining stress, and the axial stress converges to this upper limit due to slipping at the interface. The results can be used as fundamental data for the design of wellbore under depressurization-based gas production.

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Tan, C. P., E. M. Zeynaly-Andabily, and S. S. Rahman. "THE EFFECTS OF DRILLING FLUID-SHALE INTERACTIONS ON WELLBORE STABILITY." APPEA Journal 35, no. 1 (1995): 678. http://dx.doi.org/10.1071/aj94042.

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Wellbore instability, experienced mainly in shale sections, has resulted in significant drilling delays and suspension of wells in major Australian petroleum basins. These instabilities may be induced by either in-situ stresses that are high relative to the strength of the formations or physico-chemical interactions of the drilling fluid with the shales.This paper describes fundamental concepts of mud pressure penetration and flow of water between the wellbore and formation due to their chemical potential difference, and associated mud support changes as the drilling fluid interacts with shales. Due to the low permeability of shales, the penetration of the drilling fluid filtrate would result in an increase in pore pressure over a considerable distance from the wellbore. This instability mechanism strongly depends on properties of the drilling fluid filtrate and pore fluid, and the rock material composition.In addition to mud pressure penetration, water would be induced to either flow into or out of the formation depending on the relative chemical potential of the drilling fluid and the formation. A more stable wellbore condition could be achieved by optimising the chemical potential of drilling fluids.Drilling fluid and shale properties required for the models, which are determined using analytical and laboratory techniques, are presented herein. The effects of the time-dependent mechanisms on wellbore stability are demonstrated for a polyacrylamide, an ester-based and an oil-based mud. The results demonstrate that a more effective mud support can be obtained by optimising the adhesion and viscosity of the drilling fluid filtrate, and chemical potential of the drilling fluid.

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Huang, Hao Yong, Yuan Fang Cheng, Wei Zhao, Chong Cheng, and Wen Biao Deng. "Study of the Effect of Borehole Size on Wellbore Stability." Applied Mechanics and Materials 574 (July 2014): 214–18. http://dx.doi.org/10.4028/www.scientific.net/amm.574.214.

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Based on the size effect of rock strength, the borehole stability analysis model is established, which the borehole size is taken into consideration. Through this model, the relation between borehole size and collapse pressure under borehole pressure, ground stress and drilling fluid flow function is analyzed. The analysis shows that with the increase of borehole diameter, collapse pressure increases significantly, and borehole stability becomes poor, but the variation of borehole size is not proportional to collapse pressure: the bigger the borehole, the smaller the variation. When borehole diameter increases from 152.4 mm to 444.5 mm, wellbore collapse pressure increases from 1.18g/cm3 to 1.315g/cm3 and the rate of the increase is 11.44%. When slimhole drilling technology is applied, the density of minimum fluid that maintains wellbore stability is lower than the one used in conventional wellbore drilling.

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44

Irawan, Sonny, Mahmood Bataee, and Mohammad Reza Zare. "Failure Criteria and its Application in Wellbore Studies." Advanced Materials Research 1133 (January 2016): 624–28. http://dx.doi.org/10.4028/www.scientific.net/amr.1133.624.

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This paper has reviewed the failure criteria that had been applied in the wellbore studies. Rock failure studies had applied in the wellbore and reservoir to establish the stability, which is a major problem in oil and gas wells. There problems are both in injection wells and production wells. In injection wells, fracturing is a problem and in production wells, sand production affects the oil flow rate. The stress state of the well determines the stability of the well using the failure criteria.Different failure criteria and their applications had been studied. The theory of the failure has expressed; then applied criteria, formulation and modification of different criteria is expressed for different wellbore studies. And finally the important aspects and differences in wellbore failure rather than the rock surface failure has been discussed.

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45

Bybee, Karen. "Wellbore-Stability Performance of Water-Based-Mud Additives." Journal of Petroleum Technology 61, no. 09 (2009): 78–79. http://dx.doi.org/10.2118/0909-0078-jpt.

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46

Bybee, Karen. "Mitigating Wellbore Stability Problems of Water-Based Muds." Journal of Petroleum Technology 54, no. 10 (2002): 61–62. http://dx.doi.org/10.2118/1002-0061-jpt.

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47

Goodman, Harvey E. "Overview: Wellbore Stability and Sand Control (October 2004)." Journal of Petroleum Technology 56, no. 10 (2004): 66. http://dx.doi.org/10.2118/1004-0066-jpt.

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48

Hale, A. H., F. K. Mody, and D. P. Salisbury. "The Influence of Chemical Potential on Wellbore Stability." SPE Drilling & Completion 8, no. 03 (1993): 207–16. http://dx.doi.org/10.2118/23885-pa.

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49

Rawlings, C. G., N. R. Barton, S. C. Bandis, M. A. Addis, and M. S. Gutierrez. "Laboratory and Numerical Discontinuum Modeling of Wellbore Stability." Journal of Petroleum Technology 45, no. 11 (1993): 1086–92. http://dx.doi.org/10.2118/25869-pa.

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50

Ewy, Russell T., and E. Keith Morton. "Wellbore-Stability Performance of Water-Based Mud Additives." SPE Drilling & Completion 24, no. 03 (2009): 390–97. http://dx.doi.org/10.2118/116139-pa.

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