Determination of reservoir rock typing using integrating geological and petrophysical methods in one of the oil field in south-west of Iran

Mohsenipour, Abouzar; Soleimani, Bahman; Zahmatkesh, Iman; Veisi, Iman

doi:10.1007/s13146-022-00782-5

Cited by 5 publications

(2 citation statements)

References 40 publications

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“…Based on the theory of "facies control," facies refers to rocks or rock combinations formed in the same sedimentary environment with the same rock composition and genetic significance. Hence, it can be seen that the petrophysical facies are mainly controlled by sedimentary facies, diagenetic facies, and the development of fractures and vugs (Yu et al, 2022), and their classification and naming should be affected by the three aforementioned factors (Amjad et al, 2021;Hou et al, 2022a;Mohsenipour et al, 2022;Yi et al, 2022). As the basis for petrophysical facies classification in carbonate reservoirs, the sedimentary facies, diagenetic facies, and fracture and vug development characteristics of the Carboniferous reservoirs in the North Truwa oilfield were researched in this study.…”

Section: Classification Of Petrophysical Faciesmentioning

confidence: 99%

Evaluation of pore-throat structures of carbonate reservoirs based on petrophysical facies division

Hou

Zhao

et al. 2023

Front. Earth Sci.

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After complex geological transformation, such as sedimentation, diagenesis, and tectonic transformation, carbonate reservoirs have developed multiple reservoir spaces with significant heterogeneity and various pore-throat structures, including pores, vugs, and fractures. Due to these characteristics, many problems have been caused during the development of carbonate reservoirs, such as large differences between the initial production capacities of single wells and serious water channeling after injection, which have brought many challenges to the efficient development of carbonate reservoirs. Therefore, based on a reservoir evaluation method of petrophysical facies, this study classified and evaluated the pore-throat structures of Carboniferous carbonate reservoirs in the North Truwa oilfield of the Pre-Caspian Basin. Based on the data of the core, thin section, scanning electron microscope, high-pressure mercury injection, sedimentary facies, diagenetic facies, and the development of fractures and karst vugs, six reservoir petrophysical facies in the study area were classified and named, including the facies of favorable sedimentation-constructive diagenesis-fracture and vug, the facies of favorable sedimentation-constructive diagenesis-non-fracture or vug, the facies of favorable sedimentation-destructive diagenesis-fracture and vug, the facies of favorable sedimentation-destructive diagenesis-non-fracture or vug, the facies of unfavorable sedimentation-constructive diagenesis-non-fracture or vug, and the facies of unfavorable sedimentation-destructive diagenesis-non-fracture or vug. The recognition and division of diagenetic facies were based on the K-nearest neighbor. Four quantitative parameters were also selected to characterize the pore-throat structures, including displacement pressure (Pd), mercury removal efficiency (Em), median throat radius (R50), and sorting coefficient (Cs). Based on the principal component analysis, the classification and evaluation standards of pore-throat structures in different petrophysical facies were established. Combined with the flow profile measured by production logging tools, the relationship between different petrophysical facies and productions was also revealed. As a result, this study can provide suggestions for the adjustment strategy of water-driven production, which lays an important foundation for the fine development of carbonate reservoirs.

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Section: Classification Of Petrophysical Faciesmentioning

confidence: 99%

Evaluation of pore-throat structures of carbonate reservoirs based on petrophysical facies division

Hou

Zhao

et al. 2023

Front. Earth Sci.

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“…It is reported that the oil and gas production of carbonate reservoirs accounts for about 60% of the total oil and gas production in the world [ 1 ]. At present, most developed carbonate reservoirs are fractured formations with poor physical properties, uncertain fracture aperture, and strong heterogeneity [ 2 , 3 , 4 ]. The reservoir formation is easily damaged in drilling and completion operations, and the damage is not easily repaired, resulting in the decline of production [ 5 , 6 , 7 , 8 ].…”

Section: Introductionmentioning

confidence: 99%

Formation-Damage Mechanism and Gel-Breaker-Free Drill-In Fluid for Carbonate Reservoir

Fang

Zhao

Sun

et al. 2022

Gels

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Abundant oil and gas reserves have been proved in carbonates, but formation damage affects their production. In this study, the characteristics and formation-damage mechanism of the carbonate reservoir formation of the MS Oilfield in the Middle East were analyzed—utilizing X-ray diffraction, a scanning electron microscope, slice identification, and mercury intrusion—and technical measures for preventing formation damage were proposed. An ‘improved ideal filling for temporary plugging’ theory was introduced, to design the particle size distribution of acid-soluble temporary plugging agents; a water-based drill-in fluid, which did not require gel-breaker treatment, was formed, and the properties of the drill-in fluid were tested. The results showed that the overall porosity and permeability of the carbonate reservoir formation were low, and that there was a potential for water-blocking damage. There were micro-fractures with a width of 80–120 μm in the formation, which provided channels for drill-in fluid invasion. The average content of dolomite is 90.25%, and precipitation may occur under alkaline conditions. The polymeric drill-in fluid had good rheological and filtration properties, and the removal rate of the filter cake reached 78.1% in the chelating acid completion fluid without using gel breakers. In the permeability plugging test, the drill-in fluid formed a tight plugging zone on the surface of the ceramic disc with a pore size up to 120 μm, and mitigated the fluid loss. In core flow tests, the drill-in fluid also effectively plugged the formation core samples by forming a thin plugging layer, which could be removed by the chelating acid completion fluid, indicated by return permeability higher than 80%. The results indicated that the drill-in fluid could mitigate formation damage without the treatment of gel breakers, thus improving the operating efficiency and safety.

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Machine Learning of Core-Log Depth Matching: A Case Study in Carbonate Karst Reservoirs

Wang,

Liu,

Han

et al. 2023

Springer Series in Geomechanics and Geoengineering

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Determination of reservoir rock typing using integrating geological and petrophysical methods in one of the oil field in south-west of Iran

Cited by 5 publications

References 40 publications

Evaluation of pore-throat structures of carbonate reservoirs based on petrophysical facies division

Evaluation of pore-throat structures of carbonate reservoirs based on petrophysical facies division

Formation-Damage Mechanism and Gel-Breaker-Free Drill-In Fluid for Carbonate Reservoir

Machine Learning of Core-Log Depth Matching: A Case Study in Carbonate Karst Reservoirs

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