Abstract
Shale gas content is the key parameter for shale gas potential evaluation and favorable area prediction. Therefore, it is very important to determine shale gas content accurately. Generally, we use the US Bureau of Mines (USBM) method for coal reservoirs to calculate the gas content of shale reservoirs. However, shale reservoirs are different from coal reservoirs in depth, pressure, core collection, etc. This method would inevitably cause problems. In order to make the USBM method more suitable for shale reservoirs, an improved USBM method is put forward on the basis of systematic analysis of core pressure history and temperature history during shale gas degassing. The improved USBM method modifies the calculation method of the gas loss time, and determines the temperature balance time of water heating. In addition, we give the calculation method of adsorption gas content and free gas content, especially the new method of calculating the oil dissolved gas content and water dissolved gas content that are easily neglected. We used the direct method (USBM and the improved USBM) and the indirect method (including the calculation of adsorption gas, free gas and the dissolved gas method) to calculate the shale gas content of 16 shale samples of the Triassic Yanchang Formation in the Southeastern Ordos Basin, China. The results of the improved USBM method show that the total shale gas content is high, with an average of 3.97 m3/t, and the lost shale gas content is the largest proportion with an average of 62%. The total shale gas content calculated by the improved USBM method is greater than that of the USBM method. The results of the indirect method show that the total shale gas content is large, with an average of 4.11 m3/t, and the adsorption shale gas content is the largest proportion with an average of 71%. The oil dissolved shale gas content which should be paid attention to accounts for about 7.8%. The discrepancy between the direct method and indirect method is reduced by using the improved USBM method, and the improved USBM method could be more practical and accurate than the USBM method.
Highlights
With the successful exploitation of shale gas in North America [1,2,3], many Chinese scholars have begun to study China’s shale gas resources, and have found that China has a huge amount of shale gas resources [4,5,6,7]
The results of the indirect method show that the total shale gas content is large, with an average of 4.11 m3 /t, and the adsorption shale gas content is the largest proportion with an average of 71%
We provide a calculation method for adsorption shale gas content and free shale gas content
Summary
With the successful exploitation of shale gas in North America [1,2,3], many Chinese scholars have begun to study China’s shale gas resources, and have found that China has a huge amount of shale gas resources [4,5,6,7]. The accuracy of the direct method for shale reservoirs, is dependent on correctly estimating the lost shale gas content [23]. As an industrial measurement standard for coal bed methane content in the United States and China, the USBM method is widely used because of its simple operability and high accuracy. The time of coal core collection by wire coring is much shorter than the time of shale core collection by drill pipe coring These differences in depth, pressure and core collection may lead to errors in calculating the lost shale gas content. We used the direct method (USBM and the improved USBM) and the indirect method (adsorption gas, free gas and dissolved gas) to calculate the shale gas content of 16 shale samples from the Triassic Yanchang Formation in the Southeastern Ordos Basin, China
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