A data-driven hyperspectral method for sampling of diagenetic carbonate fabrics – A case study using an outcrop analogue of Jurassic Arab-D reservoirs, Saudi Arabia

Gairola, Gaurav Siddharth; Thiele, Samuel T.; Khanna, Pankaj; Ramdani, Ahmad; Gloaguen, Richard; Vahrenkamp, Volker

doi:10.1016/j.marpetgeo.2024.106691

Cited by 1 publication

(1 citation statement)

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“…Considering that the well size is so small relative to the entire ultra-thick salt formation, wellbore shrinkage can be regarded as a creep behavior under the constant temperature and load. Dorn (Gairola et al, 2024;Liu et al, 2024;Muther and Dahaghi, 2024;Xiong et al, 2024) pointed out that at a high temperature, the creep activation energy is identical to the activation energy for atomic selfdiffusion, which means that vacancy diffusion serves as the controlling mechanism of strain rate (Hunsche et al, 1992;Gairola et al, 2024;Zeng et al, 2024). On this basis, Weertman proposed the constitutive equation of the steady creep rate:…”

Section: Creep Modelmentioning

confidence: 99%

The shrinkage behavior of boreholes drilled through deepwater creeping salt formations in West Africa

Wang,

Deng,

et al. 2024

Front. Energy Res.

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Introduction: Salt formations are complex and pose significant risks during oil and gas drilling. Creep behavior in salt formations under geostress can jeopardize drilling safety.Methods: This study analyzes the shrinkage behavior of boreholes drilled through salt formations in West Africa’s Block B, with emphasis on the differential creep rates in two horizontal principal stress directions and the evolution of wellbore shape over time. The impact of drilling fluid density on shrinkage rates is also investigated.Results: After drilling through salt formations, the creep rates differ between the two horizontal principal stress directions. Shrinkage is faster in the direction of minimum horizontal principal stress and slower in the direction of maximum horizontal principal stress. Over time, shrinkage rates converge, resulting in a transition from elliptical to circular wellbore shape. Higher drilling fluid density leads to reduced shrinkage rates.Discussion: These findings contribute to the theoretical guidance for drilling fluid density selection in salt formations.

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