Using drilling data to compare geomechanical parameters with porosity (a case study, South Pars gas field, south of Iran)

Khoshnevis-zadeh, Reza; Soleimani, Bahman; Larki, Ehsan

doi:10.1007/s12517-019-4809-y

Cited by 9 publications

(1 citation statement)

References 36 publications

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“…Akbar et al (Akbar et al, 2019) established the relationship between bulk modulus and pore geometry and structure. Khoshnevis-Zadeh et al (Khoshnevis-Zadeh et al, 2019) obtained the law that there is the highest correlation between bulk modulus and porosity. Rock is a heterogeneous material, and the joint roughness can affects the bulk modulus.…”

Section: Figurementioning

confidence: 99%

Simulation study on the size effect of joint roughness on bulk modulus

Liang

Liu²,

Wang³

et al. 2023

Front. Mater.

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The bulk modulus reflects the deformation of rock macroscopically and plays a vital role in geological exploration, oilfield development, and drilling. The bulk modulus not only changes under different rock sizes, but also varies with joint roughness. Therefore, it is very important to accurately estimate the bulk modulus of rough jointed rock and evaluate its deformation. In this paper, the influence of joint roughness and rock size on bulk modulus was discussed by regression analysis of 25 sets of simulation models. The research shows that with the increase of rock size, the bulk modulus decreases exponentially, and with the rise of joint roughness, the bulk modulus increases as a power function. With the rise of joint roughness, the characteristic size of bulk modulus increases exponentially, and the characteristic bulk modulus increases as a power function. The paper gives the specific forms of these relations.

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Section: Figurementioning

confidence: 99%

Simulation study on the size effect of joint roughness on bulk modulus

Liang

Liu²,

Wang³

et al. 2023

Front. Mater.

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Feasibility study of underbalanced drilling using geomechanical parameters and finite element method

Larki

Tanha

Khosravi

et al. 2022

J Petrol Explor Prod Technol

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Wellbore instability causes main concerns in the oil and gas industry due to personnel safety and overall expenditure. Several signs such as wellbore spalling, the rate of penetration reduction, pipes sticking, well unnatural wash out, wellbore collapsing, induce fracture could indicate wellbore instability during drilling. A balance between stress concentration near the wellbore and rock strength is the primary condition for a wellbore stability during drilling. Thus, instability due to the failure of wellbore rocks occurs when the intensity of the effective stress exceeds rock strength. In underbalanced drilling (UBD), the wellbore is considered unstable since no pressure or maybe not enough pressure is applied on the well from the drilling fluid, and the pore pressure is considered undesirable stress on the wellbore, so the difference between these two pressures is applied on the wellbore. Consequently, the wellbore instability issue in the UBD approach is of great importance. UBD is mainly used to reduce the damage to geological formation and the risk of drilling fluid loss while increasing the drilling rate. This study has investigated the stability of a well in Iranian Oilfield using FLAC software considering yielded regions (plastic) for different mud weights. The investigation and analysis of the FLAC output plots, especially the plasticity plot, concluded that the ideal and optimal pressure for applying UBD conditions while also ensuring wellbore stability ranges 15.2–16.8 MPa.

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Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs

Sobhani,

Kadkhodaie,

Nabi-Bidhendi

et al. 2024

J Petrol Explor Prod Technol

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This study aims to analyze in situ stresses and wellbore stability in one of the Iranian gas reservoirs by using well log data, including density, sonic (compressional and shear slowness), porosity, formation micro-image (FMI) logs, modular formation dynamics tester (MDT), and rock mechanical tests. The high burial depth, high pore pressure, and strike-slip stress regime of the field require an optimal design of geomechanical parameters based on an integrated data set consisting of static and dynamic data, which is available for this study. Firstly, poroelastic modulus and vertical stress were calculated. Afterward, the Eaton’s equation was used to estimate pore pressure from well logging data. The geomechanical parameters were also calibrated through the interpretation of image data, the use of the modular formation dynamics tester (MDT), and laboratory rock mechanic tests. Employing poroelastic equations, the lowest and highest horizontal stresses were calculated. It was shown that the maximum horizontal stress and minimum horizontal stress correspond to sigma H and sigma h, indicating the strike-slope fault regime. The findings of this research indicated that the equivalent mud weight (EMW) resulted in 10–13 ppg suitable for the Kangan Formation and 11–14 ppg suitable for the Dalan Formation. Additionally, the well azimuth in the NE-SW direction provided the best stability for drilling the encountered formations. Therefore, the results of this study serve as cost-effective tools in planning adjacent wells in carbonate formations of gas field to predict the wellbore stability and safe mud window.

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Using drilling data to compare geomechanical parameters with porosity (a case study, South Pars gas field, south of Iran)

Cited by 9 publications

References 36 publications

Simulation study on the size effect of joint roughness on bulk modulus

Simulation study on the size effect of joint roughness on bulk modulus

Feasibility study of underbalanced drilling using geomechanical parameters and finite element method

Analyzing in situ stresses and wellbore stability in one of the south Iranian hydrocarbon gas reservoirs

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