علی شیخ الاسلام

The Cased, Cemented, and Perforated (CCP) completion method is considered one of the superior well completion methods in sand-prone reservoirs due to its execution safety and cost-effectiveness compared to alternative techniques. In the design of perforation configurations, the number of shots aligns with the requisite hydrocarbon production volume. Consequently, the optimization of the phase angle (phasing) emerges as a critical design parameter, typically deployed to forestall overlap within the impacted zones surrounding neighboring perforations and curtail their interaction. In light of the absence of constraints and the ease of establishing a single helical perforation pattern compared to alternatives, this study is dedicated to exploring the optimal phase angles within this pattern using a pythonic brute-force search approach. Moreover, emphasis is placed on achieving the minimum spacing between adjacent perforations, and the analysis is geared towards identifying the most optimal phase angles for 6, 9, and 12 shots per foot across three common wellbore diameters. Innovations of this study include the consideration of more than three consecutive wraps of perforations in determining the optimal phasing, as well as the simultaneous impact of perforation stability and uniform flow distribution around the wellbore in reducing the likelihood of sand production. The uniform distribution of perforations has been achieved by introducing a parameter known as the Equilateral Likeness Score (ELS), where its minimum value signifies the most uniform arrangement of adjacent perforations. The optimal phasing angles are determined by drawing inspiration from two distinct perspectives: maximizing the spacing between adjacent perforations and achieving the highest possible phasing values. A comparative analysis of the outcomes derived from the presented theory and existing ones underscores the potential for significant variations in the determined phasing values for certain shot densities. Ultimately, the optimal phase angles for the aforementioned shot densities are projected as 127, 130, and 97 degrees for a 41/8-inch wellbore, 130, 97, and 143 degrees for a 61/8-inch wellbore, and 97, 143, and 77 degrees for an 81/2-inch wellbore.

Due to the significance of the sand production (SP) issue in sandstone hydrocarbon reservoirs, the main objective of this study is to evaluate the Asmari formation layers along well No. 469 in the Ahwaz hydrocarbon field in terms of SP causes and its potential capacity to provide suitable solutions for its reduction from a geomechanical perspective. The evaluation was carried out using the Techlog software. The required parameters for constructing a one-dimensional geomechanical reservoir model were estimated from available data. The Mohr-Coulomb failure criterion was adopted considering the scale effect for perforated cavities under non-hydrostatic stress conditions. After constructing the one-dimensional model, the Critical DrawDown Pressure (CDDP) curve was plotted for both open hole and perforation completions, and the susceptible SP zones were identified. The M2 layer was selected as one of the most susceptible zones for SP sensitivity analysis due to its low strength, porosity, and permeability compared to other layers. The sensitivity analysis was conducted based on well geometry, formation rock properties, field stress conditions, and perforated cavity characteristics. The analysis was performed at depths of 2822 and 2837 meters in the open hole and the perforation completions, respectively, with a dominant sand diameter of 200 microns in the potential SP zone. The Critical Bottom Hole Pressure (CBHP) and the Critical Reservoir Pressure (CRP) were estimated to be 1898 and 2735 pounds per square inch, respectively, in the maximum horizontal stress direction with a 0.4-inch perforation diameter and 861 and 2115 pounds per square inch, respectively, in the direction perpendicular to the maximum horizontal stress direction with a 0.3-inch perforation diameter. By defining and determining Transitional Deviation Angle (TDA), Minimum Safe Deviation Angle (MSDA), and Critical Perforation Orientation Angle (CPOA) based on sensitivity analyses, a novel design approach for perforation operations in sand-prone reservoirs has been introduced.