In　this　work,　a　series　of　numerical　simulations　based　on　an　outcrop-data-based　discrete　fracture　network　(DFN)　model　of　the　shale　reservoir　in　the　Ordos　Basin,　China　are　conducted,　trying　to　determine　the　dependence　of　hydraulic　fracturing　on　the　properties　of　natural　fractures　and　injected　fluid.　The　accuracy　of　the　method　is　verified　through　the　PKN　solution　for　a　homogeneous　rock　model　and　a　laboratory　test　for　a　shale　sample　obtained　from　the　study　area.　Parametric　studies　are　performed　for　different　field　parameters,　including　natural　fracture　aperture,　natural　fracture　frictional　coefficient,　fluid　injection　rate　and　fluid　viscosity.　The　results　suggest　that　the　level　of　fracture　complexity　decreases　as　the　aperture　of　natural　fractures　increase,　and　increasing　the　frictional　coefficient　of　natural　fractures　can　improve　the　hydraulic　fracturing　efficiency.　Higher　injection　rates　could　translate　into　higher　injection　pressure　and　more　energy　available　for　rock　failure　near　the　wellbore,　and　therefore　improve　the　fracture　complexity.　However,　higher　fluid　viscosity　leads　to　higher　resistance　to　fracture　propagation,　and　thus　reduces　the　hydraulic　fracturing　efficiency.