Joint inversion of PP- and PS-wave for the VTI medium: application to a Lower Silurian shale-gas reservoir

2018 ◽  
Author(s):  
Guorui Ma ◽  
Feng Zhang ◽  
Xiang-Yang Li ◽  
Tuo Zhang
Keyword(s):  
Shale Gas ◽  
Joint Inversion ◽  
Gas Reservoir ◽  
Lower Silurian ◽  
Shale Gas Reservoir ◽  
Vti Medium

scholarly journals Total Porosity Measured for Shale Gas Reservoir Samples: A Case from the Lower Silurian Longmaxi Formation in Southeast Chongqing, China

Minerals ◽  
2018 ◽  
Vol 9 (1) ◽  
pp. 5 ◽  
Author(s):  
Fangwen Chen ◽  
Shuangfang Lu ◽  
Xue Ding ◽  
Hongqin Zhao ◽  
Yiwen Ju
Keyword(s):  
Shale Gas ◽  
Clay Content ◽  
Total Porosity ◽  
Gas Reservoir ◽  
Longmaxi Formation ◽  
Fine Grained ◽  
Average Value ◽  
Lower Silurian ◽  
Shale Gas Reservoir ◽  
Research Institute

Measuring total porosity in shale gas reservoir samples remains a challenge because of the fine-grained texture, low porosity, ultra-low permeability, and high content of organic matter (OM) and clay mineral. The composition content porosimetry method, which is a new method for the evaluation of the porosity of shale samples, was used in this study to measure the total porosity of shale gas reservoir samples from the Lower Silurian Longmaxi Formation in Southeast Chongqing, China, based on the bulk and grain density values. The results from the composition content porosimetry method were compared with those of the Gas Research Institute method. The results showed that the composition content porosimetry porosity values of shale gas reservoir samples range between 2.05% and 5.87% with an average value of 4.04%. The composition content porosimetry porosity generally increases with increasing OM and clay content, and decreases with increasing quartz and feldspar content. The composition content porosimetry results are similar to the gas research institute results, and the differences between the two methods range from 0.05% to 1.52% with an average value of 0.85%.

scholarly journals Organoporosity Evaluation of Shale: A Case Study of the Lower Silurian Longmaxi Shale in Southeast Chongqing, China

2014 ◽  
Vol 2014 ◽  
pp. 1-9 ◽  
Author(s):  
Fangwen Chen ◽  
Shuangfang Lu ◽  
Xue Ding
Keyword(s):  
Organic Carbon ◽  
Shale Gas ◽  
Material Balance ◽  
Model Parameters ◽  
Correction Coefficient ◽  
Hydrocarbon Generation ◽  
Gas Reservoir ◽  
Lower Silurian ◽  
Shale Gas Reservoir ◽  
Longmaxi Shale

The organopores play an important role in determining total volume of hydrocarbons in shale gas reservoir. The Lower Silurian Longmaxi Shale in southeast Chongqing was selected as a case to confirm the contribution of organopores (microscale and nanoscale pores within organic matters in shale) formed by hydrocarbon generation to total volume of hydrocarbons in shale gas reservoir. Using the material balance principle combined with chemical kinetics methods, an evaluation model of organoporosity for shale gas reservoirs was established. The results indicate that there are four important model parameters to consider when evaluating organoporosity in shale: the original organic carbon (w(TOC0)), the original hydrogen index (IH0), the transformation ratio of generated hydrocarbon (F(Ro)), and the organopore correction coefficient (C). The organoporosity of the Lower Silurian Longmaxi Shale in the Py1 well is from 0.20 to 2.76%, and the average value is 1.25%. The organoporosity variation trends and the residual organic carbon of Longmaxi Shale are consistent in section. The residual organic carbon is indicative of the relative levels of organoporosity, while the samples are in the same shale reservoirs with similar buried depths.

Characteristics of the Shale Gas Reservoir Rocks in the Lower Silurian Longmaxi Formation, East Sichuan Basin, China

2013 ◽  
Vol 31 (2) ◽  
pp. 187-219 ◽  
Author(s):  
Shugen Liu ◽  
Wenxin Ma ◽  
Lubomir Jansa ◽  
Wenming Huang ◽  
Xiangliang Zeng ◽  
...  
Keyword(s):  
Shale Gas ◽  
Sichuan Basin ◽  
Gas Reservoir ◽  
Longmaxi Formation ◽  
Reservoir Rocks ◽  
Lower Silurian ◽  
Shale Gas Reservoir
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