Relationships between the geomechanical parameters and Archie’s coefficients of fractured carbonate reservoirs: a new insight

Golsanami, Naser; Bakhshi, Elham; Yan, Wei; Dong, Huaimin; Barzgar, Ehsan; Zhang, Guangchao; Mahbaz, SeyedBijan

doi:10.1080/15567036.2020.1849463

Cited by 26 publications

(15 citation statements)

References 73 publications

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“…In this study, the rock elastic properties, unconfined compressive strength, friction angle, pore pressure, and principal stresses were estimated by using available well-logging data of Illam and Sarvak formations of the studied reservoir and empirical equations. Despite the great performance of some empirical equations like Archie's equation in carbonate and sandstone reservoirs [68], in some cases, empirical equations are not suitable to be used with all the data related to the rock physical and strength properties. In these cases, performing local calibration is emphasized.…”

Section: Resultsmentioning

confidence: 99%

“…By estimating the fluid types and their volume as well as the rock and mineral types, petrophysical studies will help to provide comprehensive information about the reservoir. Therefore, in various types of research studies, including reservoir characterization [5][6][7][8][9][10][11][12][13], hydraulic fracturing simulation/operation [14][15][16][17][18][19][20][21][22][23], and building, evaluating, and controlling numerical models [24,25], petrophysical parameters play a vital role. Porosity, permeability, and water saturation, which are considered as three main reservoir petrophysical properties, are provided by core or well-logging data.…”

Section: Introductionmentioning

confidence: 99%

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Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

Bakhshi¹,

Shahrabadi²,

Golsanami

et al. 2021

Int. J. Petrol. Technol.

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The more comprehensive information on the reservoir properties will help to better plan drilling and design production. Herein, diagenetic processes and geomechanical properties are notable parameters that determine reservoir quality. Recognizing the geomechanical properties of the reservoir as well as building a mechanical earth model play a strong role in the hydrocarbon reservoir life cycle and are key factors in analyzing wellbore instability, drilling operation optimization, and hydraulic fracturing designing operation. Therefore, the present study focuses on selecting the candidate zone for hydraulic fracturing through a novel approach that simultaneously considers the diagenetic, petrophysical, and geomechanical properties. The diagenetic processes were analyzed to determine the porosity types in the reservoir. After that, based on the laboratory test results for estimating reservoir petrophysical parameters, the zones with suitable reservoir properties were selected. Moreover, based on the reservoir geomechanical parameters and the constructed mechanical earth model, the best zones were selected for hydraulic fracturing operation in one of the Iranian fractured carbonate reservoirs. Finally, a new empirical equation for estimating pore pressure in nine zones of the studied well was developed. This equation provides a more precise estimation of stress profiles and thus leads to more accurate decision-making for candidate zone selection. Based on the results, vuggy porosity was the best porosity type, and zones C2, E2 and G2, having suitable values of porosity, permeability, and water saturation, showed good reservoir properties. Therefore, zone E2 and G2 were chosen as the candidate for hydraulic fracturing simulation based on their E (Young’s modulus) and ν (Poisson’s ratio) values. Based on the mechanical earth model and changes in the acoustic data versus depth, a new equation is introduced for calculating the pore pressure in the studied reservoir. According to the new equation, the dominant stress regime in the whole well, especially in the candidate zones, is SigHmax>SigV>Sighmin, while according to the pore pressure equation presented in the literature, the dominant stress regime in the studied well turns out to be SigHmax>Sighmin>SigV.

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Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

Bakhshi¹,

Shahrabadi²,

Golsanami

et al. 2021

Int. J. Petrol. Technol.

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show abstract

“…Golsanami et al introduced a novel approach to obtain geomechanical parameters through investigating the relationship between geomechanical parameters and Archie's coefficients. The obtained results of this study provided new insights into the simultaneous evolution of the reservoir's mechanical and petrophysical characteristic [16]. Many domestic scholars have studied the variation law of reservoir physical property parameters after long-term waterflooding development, mainly through laboratory waterflooding experiments and coring tests.…”

Section: Introductionmentioning

confidence: 94%

The Evolutionary Characteristics of Reservoir Microstructure under Long-Term Waterflooding Development and Its Fractal Description

Wang

Liu

et al. 2021

Geofluids

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Generally, long-term waterflooding development often leads to the change of reservoir pore and clay mineral composition, which results in the change of permeability and wettability. In order to explore the relationship between core micropore structure and water cut, based on physical simulation experiments and fractal theory, we proposed a fractal evolutionary model to describe the evolution characteristics of microstructure of long-term water driving reservoirs. In this paper, core pore structure by SEM was first conducted to analyze the change of core pore structure before and after waterflooding under the conditions of magnification of 200 times, 800 times, and 2000 times, respectively. Then, conventional and constant rate mercury injection tests were combined to perform the comparative analysis of core structural parameters before and after waterflooding. Finally, a micropore-throat structure evolution model of core was established. Research shows that the connectivity of larger pores becomes better after long-term water driving, the degree of heterogeneity weakens, and the micro heterogeneity of small pores becomes stronger and stronger. The throat characteristics change in a complex manner, the radius tends to increase, and the sorting becomes better, while the connectivity of small throat changes complex. In general, the heterogeneity of throat increases with the time of water injection in reservoirs with low porosity and permeability. On the basis of fractal theory and variation characteristics of rock pore structure in water driving reservoirs, we have established a micropore-throat structure evolution model of core pore-throat characteristics. This fractal evolution model quantitatively characterized the complexity and evolution law of pore structure and clarified the relationship between fractal dimension of core pore structure and water cut under different stages of water driving.

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“…Swelling of clays may occur at different stages of drilling, hydraulic fracturing, or production, which not only damages cementing quality and petrophysical logging records but also in a larger view shortens the lifetime of the borehole and causes great expenses [4]. With regard to the fluid flow, the clay-caused challenges usually include migration and concentration of clay in the pore throats, and damaging the permeability [2,5,6]. Therefore, understanding the detailed properties of the clay minerals in the hydrocarbon reservoir is of benefit for all drilling, well logging, and reservoir engineers.…”

Section: Introductionmentioning

confidence: 99%

Fractal Properties of Various Clay Minerals Obtained from SEM Images

et al. 2021

Self Cite

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Clay minerals significantly alter the pore size distribution (PSD) of the gas hydrate-bearing sediments and sandstone reservoir rock by adding an intense amount of micropores to the existing intragranular pore space. Therefore, in the present study, the internal pore space of various clay groups is investigated by manually segmenting Scanning Electron Microscopy (SEM) images. We focused on kaolinite, smectite, chlorite, and dissolution holes and characterized their specific pore space using fractal geometry theory and parameters such as pore count, pore size distribution, area, perimeter, circularity, and density. Herein, the fractal properties of different clay groups and dissolution holes were extracted using the box counting technique and were introduced for each group. It was observed that the presence of clays complicates the original PSD of the reservoir by adding about 1.31-61.30 pores/100 μm2 with sizes in the range of 0.003-87.69 μm2. Meanwhile, dissolution holes complicate the pore space by adding 4.88-8.17 extra pores/100 μm2 with sizes in the range of 0.06-119.75 μm2. The fractal dimension ( D ) and lacunarity ( L ) values of the clays’ internal pore structure fell in the ranges of 1.51-1.85 and 0.18-0.99, respectively. Likewise, D and L of the dissolution holes were in the ranges of, respectively, 1.63-1.65 and 0.56-0.62. The obtained results of the present study lay the foundation for developing improved fractal models of the reservoir properties which would help to better understand the fluid flow, irreducible fluid saturation, and capillary pressure. These issues are of significant importance for reservoir quality and calculating the accurate amount of producible oil and gas.

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Relationships between the geomechanical parameters and Archie’s coefficients of fractured carbonate reservoirs: a new insight

Cited by 26 publications

References 73 publications

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

Joint Application of Diagenetic, Petrophysical and Geomechanical Data for Selecting Hydraulic Fracturing Candidate Zone

The Evolutionary Characteristics of Reservoir Microstructure under Long-Term Waterflooding Development and Its Fractal Description

Fractal Properties of Various Clay Minerals Obtained from SEM Images

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