The　permeability　of　natural　gas　hydrate　(NGH)　turbidite　reservoirs　typically　exhibits　significant　anisotropy,　with　anisotropy　being　a　crucial　basis　for　evaluating　reservoir　production.　The　presence　of　hydrates,　as　a　crucial　constituent　of　the　solid　framework,　not　only　impacts　the　overall　permeability　but　also　influences　the　permeability　anisotropy.　To　investigate　the　saturation　sensitivity　of　permeability　anisotropy,　a　series　of　simulations　are　performed　by　integrating　particle　flow　and　computational　fluid　dynamics　methods　to　construct　the　homogeneous　and　layered　numerical　samples　and　compute　the　evolution　of　permeability　anisotropy.　It　is　shown　that　the　permeability　is　isotropic　for　homogeneous　sediments　and　the　isotropy　remains　unchanged　regardless　of　variations　in　hydrate　saturation.　The　permeability　of　layered　sediments,　in　contrast,　exhibits　significant　anisotropy　due　to　the　presence　of　dominant　channels　within　the　coarse　layer.　For　uniformly　distributed　hydrates,　the　more　effective　blockage　in　coarse　layers　results　in　a　reduction　in　anisotropy.　While　for　preferentially　distributed　hydrates,　the　excess　blocking　of　coarse　layers　makes　the　dominant　channels　transfer　to　the　fine　layers,　the　further　blocking　causes　a　U-shaped　anisotropy-saturation　curve　characterized　by　a　decrease-increase　transformation.　During　the　reservoir　production　process,　the　preponderance　channels　blocked　by　hydrates　will　be　cleared　and　the　horizontal　permeability　will　significantly　increase.　As　a　result,　the　production　efficiency　of　horizontal　wells　may　exceed　expectations.　The　findings　offer　a　parameter　support　for　production　estimation　and　environmental　assessment.