Abstract
Hydraulic fracturing is a stimulation process, most frequently used in tight and unconventional reservoirs for successful and economical hydrocarbon production. This study deals with the propagation behavior of induced hydraulic fractures (HFs) in naturally fractured formations within heterogeneous Middle Eastern tight gas reservoirs. Local sensitivity analysis was conducted for a Middle East candidate reservoir by varying fracture design parameters to investigate the fracture propagation behavior. After a comprehensive evaluation, a discrete fracture network-based simulator was used to introduce multiple sets of natural fractures (NFs) into the model to further analyze their interactions. Furthermore, simplistic wellbore placement analysis was also conducted. It is observed that production in tight reservoirs is governed by the presence of NFs and their distribution. This investigation analyzes HF propagation behavior and its correlated effects in the presence of NFs. Further assessment in terms of varying fracture geometry, NF sets, wellbore placement, and their effects on the conductivity are also presented. The introduced NF sets further illustrate the significance of the NF properties in this assessment. Additionally, variations in well placement demonstrate how effective the treatment can be in the presence of complex NF sets when properly located. The study is unique as it is one of its kind based on field data within the Middle East region and offers an insight into the potential concerns that may assist future fracturing operations within the region. The outcomes from this research validate the significance of NF orientation and its subsequent effects on the final HF geometry and network. Additionally, it further highlights the criticality of well placement and design strategies during hydraulic fracturing treatment design. Results describe how a minor modification with respect to the well placement can significantly affect hydraulic fracturing operations and subsequently the productivity and feasibility.
Highlights
Hydraulic fracturing is one of the most successful and proven reservoir-stimulation techniques, often used in low or moderate naturally producing wells
Patterns of hydraulic fractures (HFs) propagation in naturally fractured reservoirs could be affected by several factors including rock properties, pumping fluid properties, fluid pumping schedule, stress anisotropy, stress shadow caused by the interaction of different propagation streams of HFs, and the interaction of HFs with pre-existing natural fracture (NF) in the formation
The results demonstrate the significant impact of NF orientation and their corresponding effects on the resulting fracture network
Summary
Hydraulic fracturing is one of the most successful and proven reservoir-stimulation techniques, often used in low or moderate naturally producing wells. Hydrocarbon production from unconventional resources (extremely low permeability formations) is only feasible and economical through artificially induced stimulation or hydraulic fracturing, which results in the creation of a complex fracture network. This complex network is constructed by the interaction of HFs with the pre-existing formation heterogeneities including rock fabric, texture, planes of weakness, or NFs. An unconventional fracture model (UFM) is a model that presents a complex fracture network. This provided an opportunity to evaluate the models present within commercial simulators to evaluate the HF propagation behavior This comparison was based on the same reservoir conditions and treatment parameters while only varying the fracture geometry model. Permeability change: when injecting multiple proppant, the change in proppant pack permeability cannot be accounted for within the simulation
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