Quantitative multiparameter prediction of fault-related fractures： a case study of the second member of the Funing Formation in the Jinhu Sag, Subei Basin  

作　　者：Jing-Shou Liu Wen-Long Ding Jun-Sheng Dai Yang Gu Hai-Meng Yang Bo Sun 

机构地区：[1]School of Energy Resources, China University of Geosciences, Beijing 100083, China [2]Key Laboratory for Marine Reservoir Evolution and Hydrocarbon Abundance Mechanism, Ministry of Education, China University of Geosciences, Beijing 100083, China [3]Beijing Key Laboratory of Unconventional Natural Gas Geology Evaluation and Development Engineering, China University of Geosciences, Beijing 100083, China [4]Key Laboratory for Shale Gas Exploitation and Assessment, Ministry of Land and Resources, China University of Geosciences, Beijing 100083, China [5]School of Geosciences, China University of Petroleum, Qingdao 266580, Shandong, China [6]Oil Recovery Plant No.3, Zhongyuan Oilfield Co. Ltd,SINOPEC, Puyang 457001, Henan, China [7]CNOOC Energy Technology and Services-Drilling and Production Co., Tianjin 300452, China

出　　处：《Petroleum Science》2018年第3期468-483,共16页石油科学（英文版）

基　　金：supported by the Fundamental Research Funds for the Central Universities (2652017308);the National Natural Science Foundation of China (Grant Nos. 41372139 and 41072098);the National Science and Technology Major Project of China (2016ZX05046-003-001 and 2016ZX05034-004003)

摘　　要：In this paper, the analysis of faults with different scales and orientations reveals that the distribution of fractures always develops toward a higher degree of similarity with faults, and a method for calculating the multiscale areal fracture density is proposed using fault-fracture self-similarity theory. Based on the fracture parameters observed in cores and thin sections, the initial apertures of multiscale fractures are determined using the constraint method with a skewed distribution. Through calculations and statistical analyses of in situ stresses in combination with physical experiments on rocks, a numerical geomechanical model of the in situ stress field is established. The fracture opening ability under the in situ stress field is subsequently analyzed. Combining the fracture aperture data and areal fracture density at different scales, a calculation model is proposed for the prediction of multiscale and multiperiod fracture parameters, including the fracture porosity, the magnitude and direction of maximum permeability and the flow conductivity. Finally, based on the relationships among fracture aperture,density, and the relative values of fracture porosity and permeability, a fracture development pattern is determined.In this paper, the analysis of faults with different scales and orientations reveals that the distribution of fractures always develops toward a higher degree of similarity with faults, and a method for calculating the multiscale areal fracture density is proposed using fault-fracture self-similarity theory. Based on the fracture parameters observed in cores and thin sections, the initial apertures of multiscale fractures are determined using the constraint method with a skewed distribution. Through calculations and statistical analyses of in situ stresses in combination with physical experiments on rocks, a numerical geomechanical model of the in situ stress field is established. The fracture opening ability under the in situ stress field is subsequently analyzed. Combining the fracture aperture data and areal fracture density at different scales, a calculation model is proposed for the prediction of multiscale and multiperiod fracture parameters, including the fracture porosity, the magnitude and direction of maximum permeability and the flow conductivity. Finally, based on the relationships among fracture aperture,density, and the relative values of fracture porosity and permeability, a fracture development pattern is determined.

关 键 词：Fault-related fracture Quantitative prediction Development pattern Multiscale fracture Numerical simulation Jinhu Sag 

分 类 号：TE31[石油与天然气工程—油气田开发工程]