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Kewei Zu - One of the best experts on this subject based on the ideXlab platform.
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fracture responses of conventional Logs in tight oil sandstones a case study of the upper triassic yanchang formation in southwest ordos basin china
AAPG Bulletin, 2016Co-Authors: Lianbo Zeng, Kewei ZuAbstract:Fractures are the main fluid-flow pathways in tight-oil sandstones, and they have a significant influence on tight-oil distribution, exploration, and development. Cores and image Logs are commonly unavailable because of their high costs, so employing conventional Logs for fracture detection is imperative for tight-oil sandstones. We compared the fracture-response characteristics of conventional Logs based on two data sets, one from 8 cored wells with fracture intensities greater than 1 m−1 (3.3 ft−1) and the other from 11 cored wells with fracture intensities less than 0.5 m−1 (1.6 ft−1), with a case study of the Upper Triassic Yanchang Formation in southwest Ordos Basin, China. The results indicate that when tight-oil sandstones are more intensely fractured, the caliper Log, acoustic Log, compensated neutron Log, Density Log, dual induction Logs, and lateroLog 8 present fracture responses to some extent. However, it is difficult to make a distinction between fractured and nonfractured zones using conventional Logs in sandstones with smaller fracture intensities. The fracture-response intensities of conventional Logs are weak, and they are influenced by fracture abundance, fracture occurrence, fracture scale, and mineral-filling degree. Moreover, lithoLogy, fluids, and rock physical properties can cause fracturelike responses. Hence, some ambiguity exists when using conventional Logs to directly identify fractures. Accompanying fracture-sensitive conventional Logs with some methods to enhance fracture-response intensity and eliminate nonfracture influence could enable fracture identification in tight-oil sandstones.
Lianbo Zeng - One of the best experts on this subject based on the ideXlab platform.
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Fault damage zone characterization in tight-oil sandstones of the Upper Triassic Yanchang Formation in the southwest Ordos Basin, China: Integrating cores, image Logs, and conventional Logs
Interpretation, 2017Co-Authors: Wenya Lyu, Lianbo Zeng, Zonghu Liao, Peng Lyu, Shaoqun DongAbstract:AbstractFault damage zones around faults have a significant influence on fluid flow in tight-oil sandstones because they commonly act as localized conduits. Faults are developed in the tight-oil sandstones of the Upper Triassic Yanchang Formation in the southwest Ordos Basin, China. We integrate cores, image Logs, and conventional Logs from vertical wells to characterize subsurface fault damage zones in the tight-oil sandstones of the Upper Triassic Yanchang Formation in the southwest Ordos Basin, China. The results indicate that fault damage zones are intensively fractured or intensely broken in the cores. These fault damage zones present borehole collapse and widen sinusoidal curves in the image Logs. The fractures in fault damage zones are predominant high dip angles. The fracture intensity decays with the increasing orthogonal distance from the faults within a fault damage zone. In fault damage zones, acoustic Log (AC) values and compensated neutron Log (CNL) values increase; Density Log (DEN) values ...
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fracture responses of conventional Logs in tight oil sandstones a case study of the upper triassic yanchang formation in southwest ordos basin china
AAPG Bulletin, 2016Co-Authors: Lianbo Zeng, Kewei ZuAbstract:Fractures are the main fluid-flow pathways in tight-oil sandstones, and they have a significant influence on tight-oil distribution, exploration, and development. Cores and image Logs are commonly unavailable because of their high costs, so employing conventional Logs for fracture detection is imperative for tight-oil sandstones. We compared the fracture-response characteristics of conventional Logs based on two data sets, one from 8 cored wells with fracture intensities greater than 1 m−1 (3.3 ft−1) and the other from 11 cored wells with fracture intensities less than 0.5 m−1 (1.6 ft−1), with a case study of the Upper Triassic Yanchang Formation in southwest Ordos Basin, China. The results indicate that when tight-oil sandstones are more intensely fractured, the caliper Log, acoustic Log, compensated neutron Log, Density Log, dual induction Logs, and lateroLog 8 present fracture responses to some extent. However, it is difficult to make a distinction between fractured and nonfractured zones using conventional Logs in sandstones with smaller fracture intensities. The fracture-response intensities of conventional Logs are weak, and they are influenced by fracture abundance, fracture occurrence, fracture scale, and mineral-filling degree. Moreover, lithoLogy, fluids, and rock physical properties can cause fracturelike responses. Hence, some ambiguity exists when using conventional Logs to directly identify fractures. Accompanying fracture-sensitive conventional Logs with some methods to enhance fracture-response intensity and eliminate nonfracture influence could enable fracture identification in tight-oil sandstones.
Shaoqun Dong - One of the best experts on this subject based on the ideXlab platform.
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Fault damage zone characterization in tight-oil sandstones of the Upper Triassic Yanchang Formation in the southwest Ordos Basin, China: Integrating cores, image Logs, and conventional Logs
Interpretation, 2017Co-Authors: Wenya Lyu, Lianbo Zeng, Zonghu Liao, Peng Lyu, Shaoqun DongAbstract:AbstractFault damage zones around faults have a significant influence on fluid flow in tight-oil sandstones because they commonly act as localized conduits. Faults are developed in the tight-oil sandstones of the Upper Triassic Yanchang Formation in the southwest Ordos Basin, China. We integrate cores, image Logs, and conventional Logs from vertical wells to characterize subsurface fault damage zones in the tight-oil sandstones of the Upper Triassic Yanchang Formation in the southwest Ordos Basin, China. The results indicate that fault damage zones are intensively fractured or intensely broken in the cores. These fault damage zones present borehole collapse and widen sinusoidal curves in the image Logs. The fractures in fault damage zones are predominant high dip angles. The fracture intensity decays with the increasing orthogonal distance from the faults within a fault damage zone. In fault damage zones, acoustic Log (AC) values and compensated neutron Log (CNL) values increase; Density Log (DEN) values ...
Reza Rezaee - One of the best experts on this subject based on the ideXlab platform.
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the importance of geochemical parameters and shale composition on rock mechanical properties of gas shale reservoirs a case study from the kockatea shale and carynginia formation from the perth basin western australia
Rock Mechanics and Rock Engineering, 2015Co-Authors: Mohammad Mahdi Labani, Reza RezaeeAbstract:Evaluation of the gas shale mechanical properties is very important screening criteria for determining the potential intervals for hydraulic fracturing and as a result in gas shale sweet spot mapping. Young’s modulus and Poisson’s ratio are two controlling mechanical properties that dictate the brittleness of the gas shale layers. These parameters can be determined in the laboratory by testing the rock sample under different conditions (static method) or can be calculated using the well-Logging data including sonic and Density Log data (dynamic method). This study investigates the importance of the shale composition and geochemical parameters on the Young’s modulus and Poisson’s ratio using Log data. The data set of this study is coming from five different wells targeting the Kockatea Shale and Carynginia formation, two potential gas shale formations in the Perth Basin, Western Australia. The results show that converse to the common idea the effect of organic matter quantity and maturity on the rock mechanical properties of the gas shale reservoirs is not so much prominent, while the composition of the rock has an important effect on these properties. Considering the weight percentage of shale composition and organic matter quantity it could be concluded that effect of these parameters on rock mechanical properties is dependent on their weight contribution on the shale matrix. As well as effect of thermal maturity on the shale matrix and consequently on the rock mechanical properties of the shales is dependent on the organic matter content itself; therefore, obviously with a low organic matter content thermal maturity has no prominent effect on the brittleness as well.
Prabir Kumar Pal - One of the best experts on this subject based on the ideXlab platform.
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Estimation of stress magnitude and physical properties for coal seam of Rangamati area, Raniganj coalfield, India
International Journal of Coal Geology, 2010Co-Authors: Rima Chatterjee, Prabir Kumar PalAbstract:Abstract Well Log analysis has been carried out to evaluate resistivity and Density Log data of about seven wells distributed over 3.5 sq. km area of Rangamati, Raniganj coalfield, India. GeoLogical Logs of these boreholes have recorded occurrence of four major consistent coal seams (A, B, C and D) at different depths, varying between 52 to 200 m in the area. Cleat volume/porosity ranges from 1% to about 3% in this area. Vertical stress magnitude ranges from 0.55 to 4.59 MPa from 52 to 202 m and increases with depth. The gradient of vertical stress magnitude decreases within coal seams compared to the stress gradient at roof and floor of the same seams. A methodoLogy is proposed for estimation of permeability for a macro-cleat system of coal from well Log derived porosity and from known cleat spacing from Rangamati area. Permeability value ranges from 0.5 md at a depth of 193–200 m to 18 md at a shallower depth of 45–53 m while vertical stress decreases from 4.566 MPa to 1.254 MPa respectively. Permeability values of four coal seams have been correlated with effective horizontal stress to infer the maximum horizontal stress orientation.