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The AAPG/Datapages Combined Publications Database
AAPG Bulletin
Abstract
AAPG Bulletin, V.
DOI: 10.1306/12131818054
A new approach for characterization and prediction of natural fracture occurrence in tight oil sandstones with intense anisotropy
Lei Gong,1 Xiaofei Fu,2 Zhaosheng Wang,3 Shuai Gao,4 Hadi Jabbari,5 Wenting Yue,6 and Bo Liu7
1College of Geosciences, Northeast Petroleum University, Daqing, Heilongjiang, China; [email protected]
2College of Geosciences, Northeast Petroleum University, Daqing, Heilongjiang, China; [email protected]
3College of Mining Engineering, North China University of Science and Technology, Tangshan, Hebei, China; [email protected]
4College of Geosciences, Northeast Petroleum University, Daqing, Heilongjiang, China; [email protected]
5Department of Petroleum Engineering, University of North Dakota (UND), Grand Forks, North Dakota; [email protected]
6Department of Overseas Strategy and Development Planning, Research Institute of Petroleum Exploration and Development (RIPED), PetroChina, Haidian District, Beijing, China; [email protected], [email protected]
7Accumulation and Development of Unconventional Oil and Gas, State Key Laboratory Cultivation Base Jointly Constructed by Heilongjiang Province and Ministry of Science and Technology, Northeast Petroleum University, Daqing, China; [email protected]
ABSTRACT
Natural fractures provide the main path for fluid flow in tight oil reservoirs and can control the flow direction in the subsurface. Tight sandstones commonly have intense mechanical anisotropy, which means that fracture development in such tight formations may vary widely with respect to fracture orientations. However, the prediction of the degree of fracture development for each orientation is challenging. Focusing on the tight sandstones of the Chang 4 and 5 Member in the Jiyuan oil field, Ordos Basin, China, a new approach was presented for better prediction of the tectonic fracture occurrence in different directions based on fracture characterization, controlling factor, and formation mechanism analysis. First, fracture types, characteristics, formation time, and controlling factors were determined using data from outcrops, cores, and image logs. Then, triaxial tests were conducted to measure the mechanical parameters of rock samples in different directions that assessed the mechanical anisotropy of the formation and its impact on the development of fracture networks in the basin. Next, finite element numerical simulations of the paleotectonic stress field during fracturing were performed based on the fracture formation mechanism and controlling factors (lithology, bed thickness, sedimentary microfacies, and rock anisotropy). Finally, according to the failure criteria established using the measured mechanical parameters, the failure ratio and strain energy were calculated. These criteria could be employed to predict the fracture occurrence and the degree of development of each fracture network. The simulation predictions in this work are in good agreement with observed data from outcrops, cores, and image logs.
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