| Citation: | MA Yulin，HE Weiling，QIN Xuejie，et al. Geological modeling of sandstone fault-fracture reservoirs constrained by outcrop geological knowledge: A case study of Yanchang Formation reservoirs in Jinghe Oilfield, Ordos Basin[J]. Bulletin of Geological Science and Technology，2026，45（6）：1-15 doi: 10.19509/j.cnki.dzkq.tb20250420
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Tight-sandstone fault-fracture reservoirs controlled by intra-plate strike-slip faults represent important exploration targets in the southern Ordos Basin. Nevertheless, these reservoirs exhibit highly complex internal architectures. Restricted by sparse well datasets and limited seismic resolution, conventional modeling approaches cannot adequately characterize the fine-scale internal structures of small-scale strike-slip fault-fracture bodies, resulting in insufficient geological constraints for high-precision three-dimensional reservoir modeling. These limitations severely constrain sweet-spot identification and reasonable deployment of development wells for tight oil exploitation.
Taking the Triassic Yanchang Formation of Jinghe Oilfield in the southern Ordos Basin as the research case, this study constructed a geological-knowledge database for fault-fracture reservoirs based on high-resolution outcrop datasets obtained via unmanned-aerial-vehicle (UAV)-based oblique photogrammetry. A three-level hierarchical modeling workflow was proposed, comprising fault-fracture reservoir outline delineation, internal structural-zone division, and internal reservoir-attribute characterization. The external boundary of fault-fracture reservoirs was jointly constrained by outcrop-derived statistical dimensions and seismic negative-curvature attributes. A fluctuating decreasing function describing fracture-density variation was introduced to characterize fracture attenuation away from faults. Combined with fracture-density thresholds of different structural units, this function enabled quantitative division of internal zones. Constrained by fracture-orientation, height and aperture statistics from outcrop observations and borehole-imaging logs, the discrete fracture network (DFN) technique was adopted to build a 3D fracture model. During the simulation of matrix-reservoir properties, the porosity-enhancement effect induced by fracture development was fully considered.
(1) Field statistics indicated that the width of fault-fracture reservoirs in the study area mainly ranged from 80 m to 160 m, and reservoir width presented a logarithmic correlation with vertical throw of strike-slip faults. (2) Fault-fracture reservoirs were internally divided into three units: crushed zone (5–20 m in width), fracture zone (15–50 m in width), and matrix zone (40–60 m in width). Fracture density showed a fluctuating decline with increasing distance from faults, which differed from conventional monotonic exponential-decay models reported in previous studies. (3) Fracture geometrical parameters of each internal structural unit were consistent with statistical results from outcrop analogues and borehole-imaging logs. The matrix-porosity enhancement coefficient exhibited positive correlation with fracture density. Validation against actual drilling data showed that the established 3D geological model achieved a consistency of up to 75% with well-log interpretation results.
This multi-source-fusion modeling method constrained by outcrop geological knowledge effectively solves the technical bottleneck of high-precision 3D modeling for tight-sandstone fault-fracture reservoirs under sparse-well and low-seismic-resolution conditions. It can provide solid technical support for exploration-development practices in the study area and offers valuable references for research on analogous fault-fracture reservoirs in other cratonic basins.
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