An Analysis of Effect Different Fracturing Fluids on the Productivity of Multi-Stage Fractured Marcellus Shale Horizontal Wells

Abstract

Abstract The objective of this study is to assess the impact of fracturing fluid type on proppant transport and productivity of hydraulic fractures in a Marcellus Shale horizontal well. The available data from Bogges-5H well including core plug measurements, well logs, and image logs were collected and analyzed to determine shale's petrophysical and geomechanical properties. Laboratory measurements and published data were analyzed to determine the adsorption characteristics and shale compressibility including its various components (fissure, matrix, hydraulic fracture). The results of the data analysis were used as input for a hydraulic fracture model and subsequently with a reservoir model in order to investigate the impact of fluid type on proppant transport and gas productivity. The accuracy of the model was confirmed by the close match between the field and the predicted production. For the purpose of this study slickwater, high-viscosity friction reducer (HVFR), and hybrid fluid were considered for the investigation. The application of HVFR as the fracturing fluid resulted in higher fracture volume (increased fracture height) and improved productivity as compared to slickwater. Stress shadow was found to negatively impact the proppant transport, hydraulic fracture properties, and gas productivity The impact of stress shadow is more pronounced during early production due to higher production rates. The fracture treatment design in the Marcellus shale can be improved by proper fluid selection and stage spacing to mitigate the impacts of stress shadow.