Setting a New Benchmark in Tight Gas Hydraulic Fracturing: Integrated Workflow for Optimized Design, Execution, and Production from the First Horizontal Well in the M Formation in Sultanate of Oman

Abstract Hydraulic fracturing in stacked, laminated tight gas formations in central Sultanate of Oman presents significant challenges. Multistage fracturing in horizontal wells within these formations adds further complexity due to variations in stresses, stress regimes, and shale laminations. These variations can hinder fracture initiation, result in high treating pressures, and limit proppant placement. This paper introduces an integrated workflow to optimize hydraulic fracturing design through multicluster perforation with degradable solid diversion, leveraging far field acoustic diagnostics and geomechanical modeling to derisk hydraulic fracturing operations and enhance fracture placement success. A horizontal well targeting the tight gas M formation in central Sultanate of Oman was strategically landed in a shaly Sandston interval above the main reservoir to minimize the risk of water production from proximity to the water contact. Dipole sonic data with azimuthal waveforms were acquired using through bit deployment to characterize the dynamic mechanical properties and sonic imaging data along the lateral. These acoustic measurements, integrated with far field fracture detection and geological interpretations, were used to develop an innovative geomechanical model. The model enabled the identification of critical parameters for reservoir quality, completion design, and stress distribution, which guided the optimization of perforation interval selection. A multicluster fracturing strategy was implemented, incorporating degradable diverters to enhance cluster efficiency and ensure broader reservoir stimulation. Channel fracturing techniques were employed as a replacement of multiple sand/proppant slugs to initiate the fracture, facilitate the formation breakdown and manage treatment pressures, particularly given the extended lateral length. Sensitivity analyses were conducted to refine the hydraulic fracture design and mitigate the risk of fracture propagation toward the water zone. The design was validated through flowback tests after the first stage, located nearest to the water zone, and Rado Active tracer diagnostics including chemical tracers were deployed to assess diverter effectiveness. This well represents the first horizontal well drilled in the M formation within Sultanate of Oman. It was successfully completed with eight hydraulic fracturing stages, achieving 100% proppant placement. No breakdown challenges were encountered during the treatment, validating the engineered perforation interval selection. Ease of frac placement showed strong correlation with Stoneley permeability derived from the acoustic analysis, further confirming the robustness of the workflow. Tracer analysis verified diversion and placement across all clusters in two of the three stages where diverters were used, with a good indication that a multicluster approach can optimize operational efficiency and overall completion cost. Initial production exceeded expectations, delivering 2.7 times the forecasted rate, with no water breakthrough observed. This case study demonstrates the value of an integrated workflow that combines far field acoustic measurements, geomechanical modeling, and tailored stimulation strategies to unlock the potential of tight gas reservoirs in complex geological environments.