This paper aims to apply a numerical reservoir simulation incorporating geomechanical properties to determine the optimal well spacing, the number of hydraulic fracture stages per well, and the best timeframe to fracture the infill or child well in the Third Bone Spring Sand of the Delaware Basin. The field data of a multistage fractured horizontal parent well was examined to simulate the fracture propagations, then well spacing analysis between the parent and child well was performed. The optimal number of fracture stages for each well and the ideal timing for fracturing the chill well were also specified to achieve the highest estimated ultimate recovery.
The proposed workflow coupled the rock properties with a dual permeability reservoir simulation to construct a hydraulic fracture model capable of simulating 3D fracture propagations. The 1D mechanical earth model was initially developed to deliver geomechanical parameters of the studied formation. The quality of the parent well’s fracture simulation was validated using the production history matching technique. The matched model was analyzed for optimizing well spacing, fracture stages density, and the child well hydraulic fracture timing.
The results showed a normal faulting regime in the formation with the minimum, maximum, and overburden stress gradients of 0.79, 0.90, and 1.10 psi/ft, respectively. The coupled model successfully simulated fracture propagations of the parent well using the fracture treatment data. The fracture outputs were verified by satisfactorily matching the production data. The estimated fracture geometry of the parent well varies from 200 to 1050 ft fracture length and 150 to 250 ft height for each stage. The findings demonstrate that the fracture geometry complies with variations in stress conditions during fracture fluid injection. Parent well production also alters the stress orientations and magnitudes, affecting the fracture propagations of the child well. Well-spacing analysis between parent and child wells was conducted from 650 to 1300 ft with a 50 ft increment. The results specified an optimal spacing to avoid well communications and maximize total production. For hydraulic fracturing optimization, the number of fracture stages analysis was performed and converted to the optimal density of stages per well. Furthermore, the parent well’s production period is the most sensitive factor affecting the child well’s fracturing. Therefore, the ideal timeframe for child well hydraulic fracturing was provided to optimize the entire process.
The novelties of this research are in the ability to effectively estimate the optimal well spacing, fracture stages density, and timing of fracturing child well in the Third Bone Spring Sand formation using a 3D coupled model. Following the proposed workflow, one can optimize the hydraulic fracturing process in any other formations.
