Correction to: Natural fracture characterization and in situ stress orientation analysis using Fullbore Formation Micro Imager (FMI): a case study on the X oil field, Kurdistan Region, Iraq

Mahmood, Barham Sabir; Khoshnaw, Farhad A.; Abdalqadir, Mardin O.; Gomari, Sina Rezaei

doi:10.1007/s12517-023-11264-w

Cited by 2 publications

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“…When the stress exceeds the shear strength of the rock, the borehole wall produces a stress collapse phenomenon (Figure a,b). Therefore, the direction of wellbore collapse is the direction of σ h in the formation. − The drilling-induced fractures are in a group of relatively regular fractures with relatively large opening degrees and longitudinal extensions. They show two groups of 180° or close to 180° symmetrical distribution of feathery-like fractures.…”

Section: Methodsmentioning

confidence: 92%

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Detailed in Situ Stress Characterization Combining Well Logging and Improved Magnitude Calculation Model of Nos. 8+9 Coal Seam in Northeastern Ordos Basin

Wang,

Li,

et al. 2024

Energy Fuels

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The characteristics of in situ stress directly influence reservoir modification and gas production performance, and accurate evaluation of stress distribution can help improve coalbed methane production and development efficiency. Taking the deep carboniferous Nos. 8+9 coal seam in the northeastern Ordos Basin as an example, different in situ stress calculation models were evaluated with comparison to injection/falloff tests based on logging data and coal mechanical parameters. Then, the hydraulic fracture extension mechanism under different in situ stress conditions was simulated. The results show that the comprehensive use of microresistivity imaging logging and dipole array acoustic logging reveals that the main maximum horizontal principal stress direction of the Nos. 8+9 coal seam is E–W, with some area affected by faults showing NE–SW and SEE–NWW. Comparing the commonly used acoustic logging model, Huang’s model, the combined spring model, and Ge’s model, it was found that the combined spring model is more applicable. This model was optimized by adding a gas saturation parameter, decreasing the relative error of stress magnitude from 7.80 to 3.62% compared to the injection/falloff measurement results. The stress field shows vertical stress > maximum horizontal principal stress > minimum horizontal principal stress. The simulation indicates that the higher the horizontal stress difference, the smaller the fracture initiation pressure and width. The larger the injection angle, the higher the fracture initiation pressure and the smaller fracture width. The above results reveal the in situ stress distribution characteristics of the Nos. 8+9 coal seam in the northeastern Ordos Basin, providing data support for the subsequent deployment of wells and reservoir fracturing as well as guidance for deep coal seams in other basins.

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Section: Methodsmentioning

confidence: 92%

“…The direction of the horizontal principal stress can be analyzed by the fast and slow transverse wave orientation provided by the array acoustic wave anisotropy (Figure ). The use of array acoustic logging to determine the direction of the maximum in situ stress has become a common method in exploration and production. ,, …”

Section: Methodsmentioning

confidence: 99%

Detailed in Situ Stress Characterization Combining Well Logging and Improved Magnitude Calculation Model of Nos. 8+9 Coal Seam in Northeastern Ordos Basin

Wang,

Li,

et al. 2024

Energy Fuels

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Sensitivity Analysis of Hydraulic Fracturing Parameters for Optimum Horizontal Well Spacing in Tight Oil Reservoirs

Helmy,

Salem,

Elnoby

2024

Arab J Sci Eng

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Three-dimensional reservoir simulation models were developed to perform different simulation runs which aim to get an estimate for the optimal well productivity in such unconventional very low permeability reservoirs. It will take into consideration the limitations, uncertainties and capabilities of each parameter like matrix permeability, hydraulic fracturing spacing, half-length, height and conductivity to get an enhanced estimate of the optimal production ultimate recovery by using the uncertainty analysis. Hydraulic fracturing parameters with reservoir data were used to estimate the optimum well spacing distance between the horizontal wells in tight oil reservoirs. The estimated recovery factor and production forecasting using the reservoir simulation with its capabilities to get computational cases with different combinations will get the optimal well count with optimum economic evaluation. Different reservoir modeling scenarios were built with various arrangements of affecting factors. Characterizing hydraulic fracture parameters, such as fracture spacing, fracture height, fracture half-length and fracture conductivity, are studied by setting different ranges per parameter and results were investigated by comparing the oil production rate trends and total cumulative oil production after a ten-year lifetime. Sensitivity analysis was performed on the different hydraulic fracturing parameters by setting different ranges and setting the objective function to be the cumulative oil production. A complete statistical analysis for the results from the simulation runs using response surface analysis including Morris’s method and Sobol method which is a variance-based analysis was carried out. This study sensitivity analyses shed light on the long-term production behavior of tight oil reservoirs. The findings indicate that the most important parameters that influence the performance of such tight reservoirs are those related to fracture half-length and fracture height, fracture conductivity and matrix permeability. A general production trend analysis and comparisons are run for various well spacings with different numbers of wells per 100 acres (40.4687 ha). Because of their quick rates of decline, unconventional reservoirs typically favor high initial rates. Furthermore, drilling and fracturing procedures are expensive. As a result, it is crucial to quantify these fracture parameters using different data to optimize the fracture design for both single and many wells using economic analysis. The impact of the oil price and the other operational costs required for various instances will be considered in an economic evaluation based on a new well spacing optimization process. The net present value was calculated for several cases by changing the number of wells (2, 3, 4, 5, 6, 7 and 8 wells), and showed that the optimum well spacing is 300 feet (91.44 m) per 100 acres (40.4687 ha) for a tight oil reservoir.

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Correction to: Natural fracture characterization and in situ stress orientation analysis using Fullbore Formation Micro Imager (FMI): a case study on the X oil field, Kurdistan Region, Iraq

Cited by 2 publications

References 0 publications

Detailed in Situ Stress Characterization Combining Well Logging and Improved Magnitude Calculation Model of Nos. 8+9 Coal Seam in Northeastern Ordos Basin

Detailed in Situ Stress Characterization Combining Well Logging and Improved Magnitude Calculation Model of Nos. 8+9 Coal Seam in Northeastern Ordos Basin

Sensitivity Analysis of Hydraulic Fracturing Parameters for Optimum Horizontal Well Spacing in Tight Oil Reservoirs

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